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Home My WebLink About202-044 Image - loject Well History File Cover F Je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q d - 0 ~ ~ 'Well History File Identifier Organizing (dOIH)) iE CAN Color items: ~ Grayscale items: 0 Two~Sided DIGITAL DATA 7 Diskettes, No. .9-- 0 Other, Norrype 0 Poor Quality Originals: Other: 0 NOTES: BY: BEVERLY ROBIN VINCENT SHERY~INDV Project Proofing BY: BEVERL V ROBIN VINCENT SHERY~INDV Scanning Preparation I)..J' ~ -~ x 30 =jpv BY: BEVERLY ROBIN VINCENT SHER~INDY ~Rescan Needed OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner ' 0 OVERSIZED (Non-Scannable) 0 Logs of various kinds I 0 Other DATE:~ 'csjOi(lsl mP DAT~ jS/ð4- 151 m p . <J ' . j (j ~.. . 4 ~ + DAT~/I~~:~AlPAGE~;.} J Production Scanning 7 ¡ ) ., r¡ .Ij ..) Stage 1 PAGE COUNT FROM SCANNED FilE: I ~ p~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO DATE<ð11/O/fiSI VU 0 BY: BEVERLY ROBIN VINCENT SHERY~INDY BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: /s/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) ReScanned (ìpl.fi\'idoal pJg'? f:.{H)t;f,l{ ;.t10/Hiollj ..',r;,.~ìJni¡¡9 ':()mpll~lûd) RESCANNED Br: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: - YES - NO DATE: DATE: /s/ Quality Checked (dOIl'.'1 12/10/02Rev3NOTScanned_wpd OF rict, • 4§". ,v THE STATE Alaska Oil and Gas p.4of -?)WA - - Conservation Commission out GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501-3572 ALAS'' Main: 907.279.1 433 Fax: 907.276.7542 Alecia Wood Petroleum Engineer BP Exploration(Alaska), Inc. SCANNED NOV 0 2013 P.O. Box 196612 Anchorage, AK 99519-6612 c. 0 DN,- Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPE-13B Sundry Number: 313-407 Dear Ms. Wood: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this / S day of August, 2013. Encl. RECEIVED STATE OF ALASKA i JUL 2 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION Di -/ Jr APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate IS Alter Casing❑ Other c1 fZ7 e47 Li 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. s/L4.'f BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 202-044-0 •• �!34/ 3.Address: 6. er. Stratigraphic ❑ Service ✓r API Num p-p,Z9-z3,S34o^0,2.. P.O.Box 196612,Anchorage,AK 99519-6612 543-029--2i536-89-96— .0\1/40) 7.If perforating: 8.Well Name and Number: - What Regulation or Conservation Order governs well spacing in this pool? AA447.05 SBL MPE-136, Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): PYi�li3 10.Field/Pool(s): ADL0047437) 255 f g MILNE POINT, SCHRADER BLFF OIL- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): `8852 •4438 . 8765 - 4415 None 8765 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.1#NT60 32-112 32-112 Surface 2475 13-3/8"68#L-80 31-2506 31-2441.56 5020 2260 Intermediate 2476 9-5/8"40#L-80 30-2506 30-2441.56 5750 3090 Production 8819 7"26#L-80 31-8850 31 -4437.78 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment , See Attachment 2-3/8"4.7#L-80 L-80 22-8656 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths r No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0- BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0, 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 8/2/13 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: w7p/s3 WINJ El, GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: ,tw« Fe` vs o.y., GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to tlfeibest of my knowledge. Contact Alecia Wood Email Aleica.WoodlIBP.corn Printed Name Alecia Wood Title PE Signature /i Phone Date 1 n U I 3 CO 564-5492 7/29/2013 �J� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 51 ✓— 07 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS AUG - 2 201 Spacing Exception Required? Yes ❑ No lid Subsequent Form Required: /t A_a 4- ! APPROVED BY 7 Approved by: P 46+,4`.► COMMISSIONER THE COMMISSION Date: 8-1-/3 I,f ir /`3021 ' nnd� 1c tl 1isNic At Lmonths from the date of approval. Submit in Duplicate `` �j�" Form 10-403 Re ised 1/2010 Appi�v! p ,k� bp To: Mark O'Malley/Rob Handy Date: July 29, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPE-13BLS Coil Cleanout, Acidize Step Unit Operation 1 C Conduct coil cleanout of wellbore 2 C Acidize as necessary OBJECTIVE Cleanout wellbore with coil tubing post (acid soluble) class G cement MBE treatment. Acidize as necessary to regain injectivity. BACKGROUND — MPE-13B: MPE-13B was sidetracked from a Kuparuk producer and completed as an OA injector in the Schrader Bluff to support MPC-41 in 2002. Shortly after the sidetrack an MBE formed between MPE- 13B and MPC-41. MPC-41 and MPE-13B were both cycled on and off over the following year, but the connection remained. In 2004, after the drilling of new producer MPE-20A, MPE-13B was recompleted as a dual string injector in the Nb and OA. In 2008 an MBE was observed in the OA between MPE-13BLS and MPE-20A and confirmed with a red dye test. In August 2008, 6 bbls of Thermatek were pumped in MPE-13BLS (OA) and required a CT FCO to re-establish injectivity. A follow up H2Zero treatment (229 bbls) was pumped in MPE-13BLS in March 2009. This MBE treatment lasted for less than one year before another positive red dye test confirmed another direct connection. After the direct injector-producer connection was re-established another H2Zero treatment (410 bbls) was pumped in April 2010 with very limited success. In August 2010 2.5 bbls of Thermatek was pumped and again required a CT FCO to re-establish injectivity prior to pumping 400 bbls of H2Zero. Injectivity in MPE-13BLS steadily increased throughout 2011 and has remained high in 2012 indicating a breakdown of the MBE treatment once again. An MBE treatment was performed in November 2012 requiring a CT FCO after the cement was pumped, and the polymer job was completed in February 2013. The job lasted for one month before re-connecting to E-20A. As a result of the repeated breakdown of the MBE in the OA, MPE-20A has continued to cycle water and MPC- 41 has remained shut in since 2009. Cumulative injection in the OA, combined between MPE-13B and MPE-13BLS, is 1.3mmbbl. Cumulative injection in the NB in MPE-13BSS is 1.5mmbbl. A two stage 20bbl acid soluble class G Cement job was pumped in July 2013. Injectivity was established after the first 10bbls of cement but not after the second stage of squeezed cement, and a CT FCO is required to regain injectivity. • • PROCEDURE Cleanout 1. RU, hold pre-job safety meeting, PT 2. RIH and cleanout wellbore with coil tubing to bottom perf(8740'MD) 3. Perform injectivity test with KCL or PW Contingency if injectivity is not regained 4. Place up to 15bbls of HCL across perfs, allow to soak then circulate out or flush to formation using 50bbls of PW or KCL if injectivity has been established. 5. Perform injectivity test with KCL or PW raising injection pressure to a max of 4000psi if necessary injectivity.to regain inectivit 9 Y . , • III Tree:OW 2 11181 511,11 Due string Weitiest 11'x 2 3 5M FMC dual string MPE-13Bi Orig.KB Elev.=59_0'(Doyon 14) Harger dread 2.V81 EUE lop and TC-II Eitm. - _ Orig.Hgr Elev.=3055 (Doyon 14) 7."'Crikl-H BPV vote 0131.91 1*,H-4G.Welded 1 TZ Noe:7°caking is ainded on 133W 684 L-80 BTG 5193' I INIONVIIICy MOB gi S MI* L-80.ET MOE •2E35' Short String tongSE 5,Eg 2-3.I HES X-Nipple II 875.atg bcrel gm a 2-34"1-ES X- e 41.8751dg;bore 2906' KOP kV 1100' Ahem hole angle=77 deg 118 4340' We nos sidetracked 3r27.872.MMus a 250E1'-25',L7f. 7 casrg W35 run hide angle rail peen=74.deg drought window to the sue-ace.Cad shoe depth 5193' r 25#,L-90,ET MOD Casing (drift id=a 151,cap.= 0383*ft I 2-aar,4 7 elk L-80,TC-11 urbeg Oft id.=1001, 00367 be) x 2-16"1-ES X-Nipple(1.8751 pkg.borel I at 18 1 1 8117 I 2-181 I-ES X-Nippie(1.875°pig.bore) x r x 2-3,13-Barker ET Ret.real Pkr i 8150 1.945r 10 81517 2-3'&I-ES XN-14ipple IT.875'pkg bore) No-Go 1.791' I ‘517f;i Tubing tail I IMLES '41 U 0 Perforation Summary 7 x 2-191 Baker'PH Res.Pkr I 882* I mi 2.41-10. Sue Bpi Interve (i'VD) MI oi 2-318 FMS XIN-Nipple:1.8751 pkg.bore!, 81343' TP.1 e 8195'-8225' 4252'-4282' No-Go 1 7 PJ 4 88817-8880' 4384'-4391' 7 PJ 4 8720'-8740' 4402'-4407 2-3r Baker"E Hydro Trip Sub -.4 bore) 9851' 7,1%..71.171.. ..,botw,,,depth 1 1 I 2 Hyolo TrO Sub ELMO I 8'547 1 1.75"ball. 8785' 7 i-oliburton Float Collar PBTD a 8850' 7'Halliburton float shoe DATE REV.BY COMMENTS MILNE POINT UNIT 408E2 MDO Sidetrack Croce aan Nabors 27E WELL No.:PAPE-13Bi 424E2 MDO MCI perfs w CM-Ee API:50-029-22536-02 901E4 Lee Huime Recompile*as dual-Nabors 4ES BP EXPLORATION (AK) , ‘ i • i Perforation Attachment ADL0047437 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPE-13BLS 4/25/02 PER 8195 8225 4253 4263 MPE-13BLS 4/25/02 PER 8660 8680 4386 4391 MPE-13BLS 4/25/02 PER 8720 8740 4402 4408 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0047437 Well Facility Type MD Top Description TVD Top MPE-13BLS PACKER 8160 2-3/8" Baker GT Dual Packer 4242 MPE-13BLS PACKER 8631 7 X 2.375 Baker FH Ret Packer 4378 r • Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday,July 30, 2013 3:24 PM To: 'alecia.wood @bp.com' Subject: SBL MPE-13B (PTD 202-044, Sundry 313-407) Alecia, You have verbal approval to proceed with this sundry. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(a.alaska.gov 1 op rD e 2 , - ® 1-4- Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Tuesday, June 11, 2013 10:35 AM To: 'Tambe, Abhijeet' Subject: RE: MPE 13 -B Abhijeet, This email will suffice. Thanx, a , Victoria Victoria Ferguson SCANNED JUN 14 2013 Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a alaska.gov From: Tambe, Abhijeet [mailto:ABHDEET.TAMBE @ bp.com] Sent: Tuesday, June 11, 2013 10:08 AM To: Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA) Subject: RE: MPE 13 -B Thanks Guy. Good morning Victoria, Can you please advise on the sundry question 1 mentioned below? Please do not hesitate to contact me if you need any more information etc. Thanks & regards, Abhijeet Tambe Well Intervention Engineer GWO Alaska BP America 1 900 E. Benson Blvd. 1 Anchorage, AK 99508 direct: +1 907 564 4993 1 cell: +1 907 331 9184 Abhiieet.Tambe @bp.com From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, June 11, 2013 8:43 AM To: Tambe, Abhijeet Cc: Ferguson, Victoria L (DOA) Subject: RE: MPE 13 -B 1 All BP work is handled by Victoria.. • • Thanks. Guy Schwartz Senior Petroleum Engineer AOGCC 907- 444 -3433 cell 907 - 793 -1226 office From: Tambe, Abhijeet [mailto:ABHIJEET.TAMBKabp.com] Sent: Monday, June 10, 2013 4:08 PM To: Schwartz, Guy L (DOA) Subject: MPE 13 -B Hi Guy, 1 have attached an approved Sundry for MPE 13 -B. We are planning to make a couple of changes to the treatment described in this sundry. The changes are: • We will not pump any high volume gel (pump only cement) and • During pumping of the cement we will also be maintaining positive pressure on the producer (MPC -41) by pumping at min. rate Do I need to submit a new request or we can use the current approved sundry for the proposed treatment? Thanks and regards, Abhijeet Tambe Well Intervention Engineer GWO Alaska BP America k 900 E. Benson Blvd. 1 Anchorage, AK 99508 direct: +1 907 564 4993 1 cell. +1 907 331 9184 1 Abhiieet.TambePbp.com 2 • '' ®F 7,4 THE STATE Alaska it and Gas Conservation ° _ ®I _� riS��°V��1 ri ®ri11111SSlOri GOVERNOR SEAN PARNELL 333 West Seventh Avenue ti p ALAS 1 0- Anchorage, Alaska 99501 -3572 SCANNED MAY 2 9 2Q13 Main: 907.279.1433 Fax: 907.276.7542 Alecia Wood c� (3 1 # 1 1 LL eA Petroleum Engineer 0 �` BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPE -13B Sundry Number: 313 -240 Dear Ms. Wood: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P.oerster Chair DATED this Z of of May, 2013. Encl. RECEIVED STATE OF ALASKA MAY 1 3 2O 3 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations': Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: _MBE Treatment_ io ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -044-0 • 3. Address: 6. API Number Plis.I3 Stratigraphic ❑ Service El ® o 2, P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 22536 -1 -00 7. If perforating: 8. Well Name and Number. la What Regulation or Conservation Order governs well spacing in this pool? AA447.05 SBL MPE -13BE& � s 119113 Will planned perforations require a spacing exception? 1 0 Yes ❑ No ❑ 9. Property Designation (Lease Number): . * 10. Field /Pool(s): ADL MILNE POINT, SCHRADER BLFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8852 + 4438 r 8765 4415 *- None > 8765 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# NT60 32 - 112 32 - 112 Surface 2475 13 -3/8" 68# L -80 31 - 2506 31 - 2441.56 5020 2260 Intermediate 2476 9 -5/8" 40# L -80 30 - 2506 30 - 2441.56 5750 3090 Production 8819 7" 26# L -80 31 - 8850 31 - 4437.78 7240 5410 Liner None None None None None None Perforation Depth MD (ft):* Perforation Depth TVD (ft): o Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 2 -3/8" 4.7# L -80 L -80 22 - 8656 Packers and SSSV Type: See Attachment for Packer Types t Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program i0. BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/29/13 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0• GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email f►lecia.Wood( BP.corn Printed Name Alecia Wood Title PE Signature r ,, Phone Date ^°. `"-*.s 907 - 564 -5492 5/10/2013 COMMISSION USE ONLY i Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 3- 2- / b Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 2 8 2013 Spacing Exception Required? Yes ❑ No li Subsequent Form Required: JO — 4 0 /// T i APPROVED BY Approved by: / rf � �� COMMISSIONER THE COMMISSION Date: s - j Form 10 -403 Revised 1/2010 3/ / �ppOc�a p�c �i i a'd } fir •12 .. months from the date of approval. t Submit in Dupli l " ffe 1 U I \, L ^ ] L s s ro r / e \ at l/`1 11!/ `. • • by To: Mark O'Malley /Rob Handy Date: May 8, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPE -13BLS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPE -13BLS 2 F Bullhead treatment down MPE -13BLS (OA sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPE -13B was sidetracked from a Kuparuk producer and completed as an OA injector in the Schrader Bluff to support MPC -41 in 2002. Shortly after the sidetrack an MBE formed between MPE - 13B and MPC -41. MPC -41 and MPE -13B were both cycled on and off over the following year, but the connection remained. In 2004, after the drilling of new producer MPE -20A, MPE -13B was recompleted as a dual string injector in the Nb and OA. In 2008 an MBE was observed in the OA between MPE -13BLS and MPE -20A and confirmed with a red dye test. In August 2008, An MBE Treatment was performed with cement in MPE -13BLS (OA), that required a CT FCO to re- establish injectivity. A follow up polymer treatment was pumped in the OA in March 2009. This MBE treatment lasted for less than one year before another positive red dye test confirmed another direct connection. After the direct injector - producer connection was re- established another polymer treatment of a larger volume was pumped in April 2010 with very limited success. In August 2010 a cement MBE treatment was pumped and again required a CT FCO to re- establish injectivity prior to pumping the polymer job. Injectivity in MPE -13BLS steadily increased throughout 2011 and has remained high in 2012 indicating a breakdown of the MBE treatment once again. An MBE treatment was performed in November 2012 requiring a CT FCO after the cement was pumped, and the polymer job was completed in February 2013. The job lasted for one month before re- connecting to E -20A. As a result of the repeated breakdown of the MBE in the OA, MPE -20A has continued to cycle • • water and MPC -41 has remained shut in since 2009. Cumulative injection in the OA, combined between MPE -13B and MPE- 13BLS, is 1.3mmbbl. Cumulative injection in the NB in MPE -13BSS is 1.5mmbbl. PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post -job assessment meeting to capture (earnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • Tree_ CIW 21116' SM Dual string Weltheact 1 1'x2 a i r 5M F W D dual straig MPE -13Bi O r i g . KB Elev. = 513.0' (Doyon 14) Hanger thread 23/8' EUE top and TG-II Bko. — Wig. Hgr Elev. = 30.55` (Down 14) 2' -H BPV prvNe t[i Nob: 7' eyeing In WON on 20`, 91.1$, 14-40, Welded MEM 133,®` L-80, BTC 5183` 9 518' 400, L-80, IBT MOO 1 12835'1 Short Straw LINIELSlitIS I mg' I 2-318 HES X -1ha►e (18,'5' pkg. bore) p 2-318' HES X-I ie (1.875` pkg. bore) 1 2900' I KOP 49 1100' Max. hole angle = 77 deg G t 4341Y Wei MS sidetracked 3/27412. Window per Hole angle tdim t) _ 74 deg 2505° - 2522. T was nun wn,dorr to the unlace. GNd shoe depth 5193' T 28$, L-80, MT MOO CasMg (drift id =13.151. cap= .4383 bpi) 2318`. #_7 W11 L-80, TC-8 kthwrg omit id = 1.901, rap.= _00387 bpi 1 8119' I 2-318` HES X -Nhple (1.875' pkg. beret' 2 ' FES X f4thpie (1.875' pkg ( 1 8116 I T x 2.318` Baker'GT Iet. dual Pta 1 8189` I 1.945' II ?_ 81 I 2-3/8' HES XN -Nipple (1.875" pkg. bare) xN No-Go 1.781' 1 8175' 1 Tubing tail / WLEG Perforation Stannwy T x 2318" Baker FN Ret. Pkr 1 8831 I 2.41" ID. Size SpI Interval (TVD) ® 2-3t8^ HES (1.875 pkg- tare) 1 8643' 2' PJ 6 8195' -8225' 4252' - 4262' No-Go 1.791' 2' PJ 4 80817 4384' - 4391' 2' PJ 4 8720' -87417 4402' - 440T 2318" Baker E Hydro Trip Sub r/ 8' rnijeshoe pup (n h) 1 8651 I (1.98 pkg. bare) Hydro Trip Sub ELMD 1 8847 I I 8706 I T IrtaMbthlori Row Co#ar PBTO 0 1.75' ball. 8850' 1 T Halliburlon float shoe DATE REV. BY COMMENTS MILNE POINT UNIT 403/02 MOO Sideb«.k Campiebon Nabors 27E WELL No.: MPE - 13Bi 412402 MOO Add perfs w CTU - Ear API : 50 - 029 22536 - 9/1/04 Lee Hukne as dual - Nabors 4ES BP EXPLORATION (AK) • • Perforation Attachment ADL0047437 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPE -13BLS 4/25/02 PER 8195 8225 4253 4263 MPE -13BLS 4/25/02 PER 8660 8680 4386 4391 MPE -13BLS 4/25/02 PER 8720 8740 4402 4408 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • . Packers and SSV's Attachment ADL0047437 Well Facility Type MD Top Description TVD Top MPE -13BLS PACKER 8160 2 -3/8" Baker GT Dual Packer 4242 MPE -13BLS PACKER 8631 7 X 2.375 Baker FH Ret Packer 4378 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations (J Perforate Other Lf MBE Treatment Performed Alter Casing ❑ Pull Tubi Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 202 -044 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service Is 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22536 -80 -00 7. Property Designation (Lease Number): 8. Well Name and Number ADL0047437 SBL MPE -13BLS 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 8852 feet Plugs measured None feet true vertical 4438.33 feet Junk measured 8765 feet Effective Dept lee Attachment feet �J` /� (� f Casing T kL `ti� /,4--- , `'+ `' ' ` �� 1 ` Burst Collapse StNCtr 111 None None C Suck ` �� f ! ` co ` t e S pre pri . 0 0 di `� "� 5020 2260 Interme 5750 3090 �� y Produ � /1'— .1 _ . e f 'i �� 4 n , ), �1 ►r1 0 None None 1. 1`�.�.J) �.J��.! rr `.�„� Perforation de ` VUU 1� %,‘ fiC3 Tubing (size, ! _ i/ (7 j„ 22 - 4384.77 Packers and ; ", See Attachment Packer None SSSV 12. Stimulation or cement squeeze summary: — IR EC 1 V D Intervals treated (measured): SCANNED APR 16 2013 FEB 26 icV S p /� 0 Treatment descriptions including volumes used and final pressure: / i 13. Representative Daily Average Production or Inl Da CC Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator10 Development ❑ Service is Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUGD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -280 Contact Nita Summerhays Email Nita.SummerhaysaBP.com Printed Name " j Summerhays Title Petrotechnical Data Technician Alla Signature �':��i �•�5 Phone Dat . .► -ii! � , < � 564 -403 2/26/2013 FI8 DMS FEB 2 7 20 -( r3 Form 10-404 Revised 10/2012 '0/ Submit Original Only III STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 11 Repair Well U Plug Perforations U Perforate U Other MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Weil❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory p ❑ xp ry ❑ 202 -044 -0 3. Address: P.O. Box 196612 Strati ra g pl'iC Service Q 6. API Number: Anchorage, AK 99519 -6612 50 -029- 22536 -80 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047437 SBL MPE -13BLS 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 8852 feet Plugs measured None feet true vertical 4438.33 feet Junk measured 8765 feet Effective Depth measured 8765 feet Packer measured See Attachment feet true vertical 4414.56 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.1# NT60 32 - 112 32 - 112 0 0 Surface 2475 13 -3/8" 68# L -80 31 - 2506 31 - 2441.56 5020 2260 Intermediate 2476 9 -5/8" 40# L -80 30 - 2506 30 - 2441.56 5750 3090 Production 8819 7" 26# L -80 31 - 8850 31 - 4437.78 7240 5410 Liner None None None None None None Perforation depth Measured depth 8195 - 8225 feet 8660 - 8680 feet 8720 - 8740 feet True Vertical depth 4252.94 - 4262.56 feet 4385.87 - 4391.35 feet 4402.3 - 4407.75 feet 1 Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 22 - 8656 22 - 4384.77 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: [RECEIVED Intervals treated (measured): FEB 2 6L Ply Treatment descriptions including volumes used and final pressure: / ,1 0 13. Representative Daily Average Production or Iniec6o7f'Da �!" Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service IS Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSP ❑ SPLU O 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 312 -280 Contact Nita Summerhays Email Nita.Summerhaysl'a.BP.com Printed Name if Summerhays Title Petrotechnical Data Technician �� Signature Phone Date _ . � -,,i /� ��J1 /,ii_ 564 -4035 2/26/2013 R8DMS FEB 2 7 ZO; . V / Form 10-404 Revised 10/2012 /� Submit Original Only • • Daily Report of Well Operations ADL0047437 SUMMARY 4 rea men A ero ge. 'e orm success u ow ' o S psi an. ig o 4000 psi, pumped xx bbls of MEOH to confirm injection rate of x bpm @ xxx psi, swapped to PW and pumped 10 bbl spacer, swapped to H2Zero gel and pumped xxx bbl treatment, displaced with 39 bbls PW and then 10 bbls MEOH to freeze protect tubing and surface lines. 2/5/2013 « «Job complete »» ? /I /0= 150/120/0 Injectivity test Pumped 40 bbls 60740 down Lonng string tubing. Injectivity 1/31/2013 of .7 BPM at 1300 psi. Final WHPs= 1000/120/0 Attempted to pump Halliburton Ff2Zero gel treatment injection rate was too low and pressure too high. Pumped a full tubing and liner volume (35 bbls) of 60/40 MEOH final 1/12/2013 rate and pressure 0.25 bpm @ 1220 psi. « < »> Attempted to begin Halliburton H2Zero gel treatment job, could not get chemicals loaded 1/11/2013 and on location postponed job unit tomorrow 01/12/13. 1250/0/180 Attempt injectivity test down TBG post Thermatek. Pumped .6 bbls of 60/40 meth to pressure TBG to 2200 psi. Was able to established an injectivety rate of .3 bpm @ 2200 psi. Made several attempts to rock well to try to free up TBG. (unsuccessfull). 11/16/2012 Fianl WHP's 0/0 180 HES MBE Thermatek treatment: Pumped 5 bbls MEOH then 57 bbls produced water 0.5 bpm max injection pressure 1000 psi. Pumped 5 bbls Kmax gel, 10 bbls Thermatek treatment, 4 bbls Kmax gel. Displaced with 30.8 bbls diesel to freeze protect surface lines and wellbore. Good pressure responses noted during job. « < »> Will return 11 -16 -12 to 11/15/2012 perform new injectivity test and evaluate for H2Zero gel treatment. FLUIDS PUMPED BBLS 24 METH 113 PRODUCED WATER 9 KMAX GEL 10 THERMATEK TREATMENT 30.8 DIESEL 75 60/40 METH 400 H2ZERO GEL 661.8 TOTAL . . Packers and SSV's Attachment ADL0047437 SW Name Type MD TVD Depscription MPE -13BLS PACKER 8160 4182.9 2 -3/8" Baker GT Dual Packer MPE -13BLS PACKER 8631 4318.96 7 X 2.375 Baker FH Ret Packer Tree: a 2 1/16" 5M Dual Wellhead: 11" x 2 318" 5M FMC dual string M P E -13 B i Orig!'!CB Elev. = 59.0' (Nabors 27E) W Hanger thread 2 3/8" EUE top and TC -II Btm. Orig. Hgr Elev. = 30.55' (Nabors 27E) 2" CIW -H BPV profile 20 ", 91.1 #, H -40, Welded 1 112` J Note: e n casing is landed on 13 3/8 ", 68,# L -80, BTC 2506' emergency slips Well side tracked 9 5/8" 40 #, L -80, IBT MOD 2506' I A Short String Long String 2959' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore) I 2966' KOP @ 1100' Max. hole angle = 77 deg @ 4340' Well was sidetracked 3/27/02. Window Hole angle thru perfs = 74 deg @ 2506' - 2522' . 7" casing was run g P g through window to the surface. Old shoe depth 5193' 7" 26 #, L -80, IBT MOD Casing (drift id = 6.151, cap.= .0383 bpf) 2 -3/8 ", 4.7 #/ft L -80, TC -II tubing (drift id = 1.901, cap. = .00387 bpf) 8119' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore) I 8116' 7" x 2 -3/8" Baker 'GT' Ret. dual Pkr 8160' 99%970 90,09 89 ,ra 1.945" ID. I 8169' 2 -3/8" HES XN- Nipple (1.875" pkg. bore) xN No -Go 1.791" 8175' I Tubing tail / WLEG I I I I Perforation Summary 7" x 2 -3/8" Baker 'FH' Ret. Pkr 1 8631' I 2.41" ID. Size Spf Interval (TVD) . XN 2 -3/8" HES XN- Nipple (1.875" pkg. bore) 8643' I 2" PJ 6 8195' -8225' 4252' - 4262' 1 No -Go 1.791" 2" PJ 4 8660' -8680' 4384' - 4391' 2" PJ 4 8720' -8740' 4402' - 4407' r eA 2 -3/8" Baker 'E' Hydro Trip Sub w/ 6' muleshoe pup (bottom depth) 8651' (1.97" pkg. bore) Hydro Trip Sub ELMD 1 8647' I 1.75" ball. 1 8765` 7" Halliburton Float Collar PBTD z firozzy 1 8850' I 7" Halliburton float shoe /7 '!� • DATE REV. BY COMMENTS 4/06/02 MDO Sidetrack Completion Nabors 27E MILNE POINT UNIT WELL No.: MPE -13Bi 4/24/02 MDO Add perfs w CTU - E -line API : 50 -029- 22536 -02 9/1/04 Lee Hulme Recomplete as dual - Nabors 4ES BP EXPLORATION (AK) tiLCEIVED STATE OF ALASKA DEC �� A I�I OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon LJ Repair Well U Plug Perforations LJ Perforate Li Other U MBE Treatment Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory ❑ ,, 202 -044 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service El 6. API Number: 0 Anchorage, AK 99519 -6612 a 50- 029 - 22536 - operty Designation (Leasg Number): 8. Well Name and Number: \\ \C�\ ;?-5.-5 1 f ADL0047437 - MPE -13BLS - Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 8852 feet Plugs measured None feet true vertical 4438.33 feet Junk measured 8765 feet Effective Depth measured 8765 feet Packer measured See Attachment feet true vertical 4414.56 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.1# NT60 32 - 112 32 - 112........ 0 0 1 Surface 2475 13 -3/8" 68# L -80 31 - 2506 31 - 2441.56 5020 2260 Intermediate 2476 9 -5/8" 40# L -80 30 - 2506 30 - 2441.56 5750 3090 Production 8819 7" 26# L -80 31 - 8850 31 - 4437.78 7240 5410 Liner None None None None {�+y None None Perforation depth Measured depth See Attachment feet �� >Y1Q 1 120.3 True Vertical depth See Attachment feet fY� Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 22 - 8656 22 - 4384.77 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attffd men4• -' —A See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 305 380 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 4 111 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSPEI SPLUG p 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -280 Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 E -mail Nita.Summerhayst1 bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician / Signatur �/� "7�� , �� Phone 564 -4035 Date 12/18/2012 .i_ t- % t. ,, SrJ / 2 •by / L Form 10-404 Revised 11/2011 / Submit Original Only le i • Daily Report of Well Operations ADL0047437 HES M ,r u BE Thermatek treatment: Pumped 5 bbls MEOH then 57 bbls produced water 0.5 b injection pressure 1000 psi. Pumped 5 P m max in P 1 p P s P bbls Kmax gel, 10 bbls Thermatek treatment, 4 bbls Kmax gel. Displaced with 30.8 bbls diesel to freeze protect surface lines and wellbore. Good pressure responses noted during job. Will return 11 -16 -12 to perform new injectivity test and evaluate for 15- Nov -12 H2Zero gel treatment. FLUIDS PUMPED BBLS 30.8 DIESEL 5 METH 9 KMAX GEL 10 THERMATEK 54.8 TOTAL • • Perforation Attachment ADL0047437 Perf Opera Meas Meas Operation tion Depth Depth TVD Depth TVD Depth SW Name Date Code Top Base Top Base MPE -13BLS 4/25/02 PER 8195 8225 4252.94 4262.56 MPE -13BLS 4/25/02 PER 8660 8680 4326.87 4332.35 MPE -13BLS 4/25/02 PER 8720 8740 4343.3 4348.75 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET 01-1 HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Tree: CIW 2 1/16" 5M Dual st ill - Wellhead: 11" x 2 3/8" 5M FMC dual string Orig. Elev. = 53.8' (Nabors 27E) 9 M P E 13 B i Orig. Hgr Elev. = 28.7' (Nabors 27E) Hanger thread 2 3/8" EUE top and TC -II Btm. - 2" CIW -H BPV profile 20 ", 91.1#,1-1-40, Welded 1112' 1 1 13 3/8 ", 68,# L -80, BTC 2506' I Note: 7" casing is landed on emergency slips Well side tracked 9 5/8" 40 #, L -80, IBT MOD 12506' 1 Short String Long String 1 2959' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore) 1 2966` 1 KOP @ 1100' Max. hole angle = 77 deg @ 4340' Well was sidetracked 3/27/02. Window Hole angle thru perfs = 74 deg © 2506' - 2522' . 7" casing was run 9 P g through window to the surface. Old shoe depth 5193' 7" 26#, L -80, IBT MOD Casing (drift id = 6.151, cap.= .0383 bpf) 2 -3/8 ", 4.7 #/ft L -80, TC -II tubing (drift id = 1.901, cap. = .00387 bpf) 1 8119' 12 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore) 1 8116' 1 �r 7" x 2 -3/8" Baker'GT' Ret. dual Pkr 1 8160' 1 ;;r 1.945" ID. 8169' 1 2 -3/8" HES XN- Nipple (1.875" pkg. bore) XN No -Go 1.791" 1 8175' 1 Tubing tail / WLEG N rr:.f ffr�fF;, Perforation Summary T' x 2 -3/8" Baker'FH' Ret. Pkr 1 8631' 1 2.41" ID. Size Spf Interval (TVD) � 2 -3/8" HES XN- Nipple (1.875" pkg. bore) 1 8643' 1 2" PJ 6 8195' -8225' 4252' - 4262' e�"7!> No -Go 1.791" 2" PJ 4 8660' -8680' 4384' - 4391' '' 2" PJ 4 8720' -8740' 4402' - 4407' 2 -3/8" Baker 'E' Hydro Trip Sub w/ 6' muleshoe pup (bottom depth) 1 8651' (1.97" pkg. bore) H E Hydro Trip Sub ELMD 8647' 1 1 8765' 1 7" Halliburton Float Collar PBTD 0 1.75" ball. 1 8850' I 7" Halliburton float shoe • DATE REV. BY COMMENTS 4/06/02 MDO Sidetrack Completion Nabors 27E MILNE POINT UNIT WELL No.: MPE -13Bi 4/24/02 MDO Add perfs w CTU - E -line API : 50 -029- 22536 -02 9/1/04 Lee Hulme Recomplete as dual - Nabors 4ES BP EXPLORATION (AK) u • - w�� \\ I i% s THE STATE Alaska Oil and Gas 7ibir "' ° l l lS onservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF �. Anchorage, Alaska 99501 -3572 ALAS SCANNED JAN 2 3 2013 Main: 907.279.1433 Fax: 907.276.7542 Chad Wermager I L Milne Point Production Engineer g.1) 1 BP Exploration Alaska p (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, Milne PT Unit SB E -13B Sundry Number: 312 -464 Dear Mr. Wermager: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this ?- day of December, 2012. Encl. R Y D e • 40 A DEC 4 6 2012 STATE OF ALASKA A 1,/ t 2 I R- D ALASKA OIL AND GAS CONSERVATION COMMISSION V A A APPLICATION FOR SUNDRY APPROVALS �(� V 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ A - ► Stimulate in • Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -044-0 • 3. Address: 6. API Number. Stratigraphic ❑ Service El • so - o aq - 2.153(e x ' P.O. Box 196612, Anchorage, AK 99519 -6612 7 10 -11 aS 7. If perforating: 8. Well Name and Number. ,S6 What Regulation or Conservation Order governs well spacing in this pool? MILNE PT UNIT JO E -138 ?Kh Will planned perforations require a spacing exception? Yes ❑ No ❑ tIA 9. Property Designation (Lease Number): PLI3 10. Field /Pool(s): ADL0047437 5518 101 2912- MILNE POINT, SCHRADER BLFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8852 • 4438 8765 . 4415 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# NT60 32 - 112 32 - 112 Surface 2475 13 -3/8" 68# L -80 31 - 2506 31 - 2441.56 5020 2260 Intermediate 2476 9 -5/8" 40# L -80 30 - 2506 30 - 2441.56 5750 3090 Production 8819 7" 26# L -80 31 - 8850 31 - 4437.78 7240 5410 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8660 - 8680 4385.87 - 4391.35 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service igi • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/11/12 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Wermager Email Chad.WermagertBP.Com Printed Name Chad Wermager Title Milne Point Production Engineer Signature C � ��_ Phone 564 -5257 Date a/6.7/ Phone by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 511- `'1 (011 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS DEC 13 2 � ' 7 Spacing Exception Required? Yes ❑ No Ef Subsequent Form Required: /O - 4 1 01 1 / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / 2 [ 12. l l Z / a -/o./z_ ciR lroRriNiAL Approved application is valid for 12 months from the date of approval. Submit in Duplicate �� °tv • • Packers and SSV's Attachment ADL0047437 Well Facility Type MD Top Description TVD Top MPE -13BLS PACKER 8165 2 -3/8" Baker GT Dual Packer 4243 MPE -13BLS PACKER 8636 7 X 2.375 Baker FH Ret Packer 4320 Casing Summary ADLOO47437 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.1# NT60 32 112 32 112 NT60 INTERMEDIAT 2476 9 -5/8" 40# L -80 30 2506 30 2442 5750 3090 L -80 PRODUCTION 8819 7" 26# L -80 31 8850 31 4438 7240 5410 L -80 SURFACE 2475 13 -3/8" 68# L -80 31 2506 31 2442 5020 2260 L -80 TUBING 8634 2 -3/8" 4.6# L -80 22 8656 22 4385 11200 11780 L -80 TUBING 8158 2 -3/8" 4.6# L -80 22 8180 22 4248 11200 11780 L -80 • • 1 bp • • 0 To: Mark O'Malley /Rob Handy Date: November 26, 2012 MPU Well Operations Supervisor From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPE -13BLS Coil Cleanout, Acidize Step Unit Operation 1 C Conduct coil cleanout of wellbore 2 C Acidize as necessary OBJECTIVE 1. Cleanout wellbore with coil tubing post MBE treatment. Acidize as necessary to regain injectivity. PROCEDURE Cleanout 1. RU, hold pre -job safety meeting, PT 2. RIH and cleanout wellbore with coil tubing to bottom pert (8740 MD) 3. Perform injectivity test with produced water. Contingency if injectivity is not regained 4. Spot 3.5bbls of HCI across perfs, do not squeeze into formation (WBV from bottom perf to Tubing Tail is 3.4bbls, do not want to acidize the thermatek in the matrix and compromise the treatment). Allow to soak then circulate out or flush to formation using 50bbls of PW if injectivity has been established. 5. Perform injectivity test with produced water raising injection pressure to a max of 4000 psig if necessary. Tree: CIW 2 1/16" 5M Dual s M P E -13 Bi Orig. Elev. = 53.8' (Nabors 27E) Wellhead: 11" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" EUE top and TC -II Btm. Orig. Hgr Elev. = 28.7' (Nabors 27E) 2" CIW -H BPV profile ' 20 ", 91.1 #, H -40, Welded 1112' 13 3/8 ", 68,# L -80, BTC 12506' 1 emergency Note: 7" slips casing is landed on Well side tracked 9 5/8" 40 #, L -80, IBT MOD 2506' Short String Long String 2959' I 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2966' KOP @ 1100' Max. hole angle = 77 deg @ 4340' Well was sidetracked 3/27/02. Window @ 2506' - 2522' . 7" casing was run Hole angle thru perfs = 74 deg through window to the surface. Old shoe depth 5193` 7" 26 #, L -80, IBT MOD Casing (drift id = 6.151, cap.= .0383 bpf) 2 -3/8 ", 4.7 #/ft L -80, TC -II tubing (drift id = 1.901, cap. = .00387 bpf) 8119' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore) 1 8116' ■1 7" x 2 -3/8" Baker `GT' Ret. dual Pkr 1 8160` J 1.945" ID. 8169' I 2 -3/8" HES XN- Nipple (1.875" pkg. bore) xN No -Go 1.791" NM 8175' I Tubing tail / WLEG 11 Perforation Summary 7" x 2 -3/8" Baker `FH' Ret. Pkr ( 8631' 2.41" ID. Size Spf Interval (TVD) XN, 2 -3/8" HES XN- Nipple (1.875" pkg. bore) 8643' 2" PJ 6 8195` -8225' 4252' - 4262' , No -Go 1.791" 2" PJ 4 8660' -8680' 4384' - 4391' 2" PJ 4 8720' -8740' 4402' - 4407' VA 2 -3/8" Baker `E' Hydro Trip Sub w/ 6' muleshoe pup (bottom depth) 1 8651' (1.97" pkg. bore) q N Hydro Trip Sub ELMD 1 8647' rGp r 0 1.75" ball. 1 8765' I 7" Halliburton Float Collar PBTD 8850' 7" Halliburton float shoe DATE REV. BY COMMENTS MIILNE POINT UNIT 4/06/02 MDO Sidetrack Completion Nabors 27E WELL No.: MPE -13Bi 4/24/02 MDO Add perfs w CTU - E -line API : 50 -029- 22536 -02 9/1/04 Lee Hulme Recomplete as dual - Nabors 4ES BP EXPLORATION (AK) 2A WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland .....• -�-- 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 �� FEB 2 7 2413. RE: Multifinger Imaging Tool: CD2 -16 Run Date: 9/14/2012 The technical data listed below is being submitted herewith. Please address...any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2 -16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20426 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 Klinton Wood @halliburton.com Date: 1,0 ZZ Z Signed: AlLa.. ��1�� • • • r„ r-7 F )' �� a e 3 `a SEAN PARNELL, GOVERNOR -�4 U Li N� ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Alecia Wood Production Engineer BP Exploration (Alaska), Inc. 4ur 1 C I" P.O. Box 196612 �� © / Li. /� I Anchorage, AK 99519 -6612 r} ` Re: Milne Point Field, Schrader Bluff Oil Pool, MPE -13BLS Sundry Number: 312 -280 Dear Ms. Wood: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy P. oerster Chair sI DATED this i day of August, 2012. Encl. „�✓ RECEIVED • STATE OF ALASKA JUL 2 5 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations - \/ , \ \ ❑ Pull Tubing El /145 e-. , �� J er„ ro<r,❑,/ Operations Shutdown ❑ Re -enter Susp. Well 1E] - 1 Stimulate El Alter Casing ❑ `./ Other. J I ',L 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: V - '' 12 - BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -044-0 ` 1 3 " 3. Address: Stratigraphic El Service 6. API Number: 50, �.29. Zzs-3� . -�Z P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 6=01 0 -7 3; rL 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: / property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ID MPE -13BLS 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0047437 ' MILNE POINT, SCHRADER BLFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8852 • 4438 • 8765 4415 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20 "91.1 #NT60 37 -117 37 -117 Surface 2489 13 -3/8" 68# L -80 33 - 2522 33 - 2455.6 5020 2260 Intermediate 2490 9 -5/8" 40# L -80 32 - 2522 32 - 2455.6 5750 3090 Production 8824 7” 26# L -80 31 - 8855 31 - 4439.15 7240 5410 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 2 -3/8" 4.6# L -80 4326 22 - 8656 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSV Installed No SSV Installed 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: 8/21/12 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ Q GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Prepared by Garry Catron 564 -4424 Printed Name Alecia Wood Title Production Engineer Signature .. Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' E3 2 • 28 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: APPROVED BY / 7 Approved by: COMMISSIONER THE COMMISSION Date: 9 — —/ G� Form 10 -403 Re ised 1/2010 m. d 0 1 20 S u bmit in Duplicate, tv 1/3 j 12 � C' A414/12- 1 • • • Packers and SSV's Attachment ADL0047437 Well Facility Type MD Top Description TVD Top MPE -13BLS PACKER 8165 2 -3/8" Baker GT Dual Packer 4243 MPE -13BLS PACKER 8636 7 X 2.375 Baker FH Ret Packer 4379 • • Perforation Attachment ADL0047437 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPE -13BLS 4/25/02 PER 8660 8680 4386 4391 MPE -13BLS 4/25/02 PER 8720 8740 4402 4408 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF I • • bp To: Mark O'Malley /Rob Handy Date: July 17, 2012 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPE -13BLS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPE -13BLS 2 F Bullhead treatment down MPE -13BLS (OA sand). Keep well and offset ✓ producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPE -13B was sidetracked from a Kuparuk producer and completed as an OA injector in the Schrader Bluff to support MPC -41 in 2002. Shortly after the sidetrack an MBE formed between MPE - 13B and MPC -41. MPC -41 and MPE -13B were both cycled on and off over the following year, but the connection remained. In 2004, after the drilling of new producer MPE -20A, MPE -13B was recompleted as a dual string injector in the Nb and OA. In 2008 an MBE was observed in the OA between MPE -13BLS and MPE -20A and confirmed with a red dye test. In August 2008, An MBE Treatment was performed with cement in MPE -13BLS (OA), that required a CT FCO to re- establish injectivity. A follow up polymer treatment was pumped in the OA in March 2009. This MBE treatment lasted for less than one year before another positive red dye test confirmed another direct connection. After the direct injector - producer connection was re- established another polymer treatment of a larger volume was pumped in April 2010 with very limited success. In August 2010 a cement MBE treatment was pumped and again required a CT FCO to re- establish injectivity prior to pumping the polymer job. Injectivity in MPE -13BLS steadily increased throughout 2011 and has remained high in 2012 indicating a breakdown of the MBE treatment once again. As a result of the repeated breakdown of the MBE in the OA, MPE -20A has continued to cycle water and MPC -41 has remained shut in since 2009. Cumulative injection in the OA, combined between MPE -13B and MPE - 13BLS, is 1.043mmbbl. Cumulative injection in the NB in MPE -13BSS is 1.387mmbbl. • • PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post -job assessment meeting to capture (earnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • Tree- C111/ 2 1 4 6M Cual string Welbeatt 1 r x 2 34* 5MFMC dual string MPE-13Bi Orig. K.B Elev. = 561.0" (Doyon 14) Hanger tweed 238 EUE top and TC-II B. Ong 14gr Elev. = 30,55' (Doyen 14) 2" CIW-I4 BPV profle 20. 91 1404-40 welded I 112' IL Note; casing le bindw on 13 IV 88 L-80. STD 1.51q2' I oniergency 9 518' 404 L-80. ST MOO I C Snort String LalltiLfikirig I I 2-319" I4ES X-44puile 275" peg bore, gi HES X46pple 11.875 Ixtg bar ei 268 ' I KOP (&14: 11Y Max. hole are = 77 deg Well teas sidetlacired 327432_ Window .41 2506' - 2. T easing was nal. Hole angle tftrri perla 74 deg trough winckar to the surface. Cle siroe depth 5193' 264, L40, IBT MOO Casing idrtfUtl = 15/ cap twit 2-348, 47t LAG, TC-11 eking lchrilt = 141:431, cap =03387 bull I 2-30r FES X-Nipple 41 875 Og. hire I ai-t I I .3 2-10 FrES X-Nippre itam plug. bow: 131 ; 1„ I R. 2-2.8' Eater' '57 Ret. twat Pia I 3 15-2 I I E 1 ;24" I 2-306" 1.875' pkg. bons NeOn 1 701" Tubmg tail WILES Perforation Summary x 2-3i6" Baker "FhT Ret. Pr I 281 I 2.41" ID Site Spi Interval (TVD) 2-318r HES XN-Nipple 41.875 pkg. boret I Eie43' I 1 8195' -8225' 425Z - 425r2' No-Go 1 par 2' PJ 4 8060' -HST 4384'- 4391' T PJ 4 87211' -8740' 4402'- 4407' 2-3111" Baker E itrdro Trip Sub ei 8' mixteshoe pup (bat= depthl I 64351 I I 1.9r pkg. bowel Hy d r o T r i p Sub ELMO I 9X"' I I 8 I rnFlatCdllarPETD 0 CS b.W. I 8850' I 7' Nalliburton ioat sCo 4 1. DATE REV, BY GlYaiMENTS 40642 MCC 3idetracit Complerion Nabors 27E MILNE POINT UNIT WELL No.: MPE 424102 UDC And perfs `14 CTU - E-line API : 50 tros 1-luIrne Recornplete as dual - Nabors 4E: BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 - — - Post Office Box 196612 Anchorage, Alaska 99519 -6612 rifr December 30, 2011 s ' ED FEB 2 2 2012 - 1; " be nci Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue rh Anchorage, Alaska 99501 ea,o D.-- 0 1 4 Subject: Corrosion Inhibitor Treatments of MPE -Pad y\/� _ 13 PI Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE-04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE-05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE-08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 - OP MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/1012011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002080 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate El Other Q MBE TREATMENT Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver[] Time Extension ❑ D A Zo Nf— Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ f 202 -0440 3. Address: P.O. Box 196612 Stratigraphic❑ Service Q 6. API Number: 02-30 Anchorage, AK 99519 -6612 50- 029 - 22536- - 8A•Q0. (j b 8. Property Designation (Lease Number) : :1M 9 . Well Name and Number: ADLO- 047437 $ (( 7_1 1 Q a MPE -13BLS 10. Field /Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 8852 feet Plugs (measured) None feet true vertical 4438.33 feet Junk (measured) None feet Effective Depth measured 8765 feet Packer (measured) 8160 8631 feet true vertical 4414.56 feet (true vertical) 4242 4378 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.1# H-40 SURFACE - 112 SURFACE - 112 1490 470 Surface 2475' 13 -318" 68# L -80 SURFACE - 2506 SURFACE - 2445 5020 2270 Intermediate 2476' 9 -5/8" 40# L -80 SURFACE - 2506 SURFACE - 2445 6870 4760 Production 8819' 7" 26# L -80 SURFACE - 8850 SURFACE - 4438 7240 5410 Liner y Liner Perforation depth: Measured depth: SEE ATTACHED - — — — True Vertical depth: Tubing: (size, grade, measured and true vertical depth) LS 2 -3/8" 4.7# L -80 SURFACE - 8651 SURFACE - 4383 Packers and SSSV (type, measured and true vertical depth) 7" X 2 -3/8" BAKER GT RET DUAL PKR 4242 7" X 2 -3/8" BAKER FH RET PKR t 4378 a 12. Stimulation or cement squeeze summary: Intervals treated (measured): OCT 2 9 # Z 010 e Treatment descriptions including volumes used and final pressure: ail 91 Ma s c ons_ CO 13. Representative Daily Average Production ata Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas Lj WDSPL GSTOR ❑ WINJ WAG[ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 30-2-47 Contact Keith Lopez Printed Name Keith Lopez Title PE Signature Phone 564 -5718 Date 10/25/2010 riB�„ �Vis NOV O 2 Znm ll 3 �a �is Form 10-404 Revised 10/2010 Submit Odgi al Only MPE -13BLS 202 -044 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tv d Depth To Tvd Depth Bas MPE -13B 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE -13B 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE -13BLS 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE -13BLS 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE -13B 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 MPE -13BSS 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 MPE -138LS 4/4/10 SQZ 8,660. 8,740. 4,385.87 4,407.75 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED - kE - MOVEID SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE s • MPE -13BLS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/21/2010 Job Scope: ,Pump gel to treat MBE in an attempt to restore injecton in the OA zone. Pumped to following schedule: 5 bbls 60/40 meth water spear, 15 bbls of produced water spacer, 298 bbls of 400 bbls planne ... Continue WSR on 10/22/2010... 10/22/20101Job Scope: Pump gel to treat MBE in an attempt to restore injecton in the OA zone. Pumped to following schedule: 5 bbls 60/40 meth water spear, 15 bbls of produced water spacer, 102 bbls of Polymer, 39 bbls of produced water, 10 bbls of 60/40 tubing, this puts 15 bbls of produced water into formation. Job report from HES will be e- mailed to Lau * **Job Complete * ** { � I � I FLUIDS PUMPED BBL 400 POLYMER 20 60/40 METH 69 PRODUCED WATER 489 TOTAL Allik Tree: CIW 2 x 2 3/8" 5M FMC dual string 5M Dual string M Wellhead:l l" x 2 P E 13 B I Orig. KB Elev. = 59.0` (Doyon 14) Hanger thread 2 3/8" EUE top and TC -II Btm. Orig. Hgr Elev. = 30.55' (Doyon 14) 2" CIW -H BPV profile WE �R 20 ", 91.1 #, H -40, Welded 112' 13 3/8 ", 68,# L -80, BTC 5193' ' , Note: 7" casing is landed on emergency slips 9 5/8" 40 #, L -80, IBT MOD 12835` f r Short String Long String ...�•. , ter;" 2959' 2 -3/8" HES X- Nipple (1.875" pkg. bore)' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2966 fr � �i Nf, KOP @ 1100` ,r Max. hole angle = 77 deg @ 4340` Well was sidetracked 3/27/02. Window le thru erfs = 74 de % f @2506'-2522'. 7" casing was run Hole angle p g through window to the surface. Old shoe depth 5193` rr f 7"26#, L -80, IBT MOD Casing (drift id = 6.151, cap.= .0383 bp f) r 2 -3/8 ", 4.7 #/ft L -80, TC -II tubing 'S (drift id = 1.901, cap. = .00387 bpi) s 8119' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore) 8116` 7" x 2 -3/8" Baker'GT' Ret. dual Pkr 8160` 1.945" ID. 8169` 2 -3/8" HES XN- Nipple (1.875" pkg. bore) No -Go 1.791" f' 8175` Tubing tail / WLEG Perforation Summary 7" x 2 -3/8" Baker'FH' Ret. Pkr F863V 2.41" ID. Size Spf Interval (TVD) %* » F. 2 -3/8" HES XN- Nipple (1.875" pkg. bore) 8643` 2" PJ 6 8195'-8225' 4252'-4262' „ No-Go 1.791" 2" PJ 4 8660'-8680' 4384' - 4391' 2" PJ 4 8720'-8740' 4402'-4407' 2 -3/8" Baker'E' Hydro Trip Sub 8651` w/ 6` muleshoe pup (bottom depth) (1.97" pkg. bore) Hydro Trip Sub ELMD 8647' 8765' 7" Halliburton Float Collar PBTD 1.75" ball. 8850` 7" Halliburton float shoe DATE REV. BY COMMENTS MILNE POINT UNIT 4/06/02 MDO Sidetrack Completion Nabors 27E WELL No.: MPE - 1313i 4/24/02 MDO Add perfs w CTU - E -line API : 50 - 22536 - 9/1/04 Lee Hulme Recomplete as dual - Nabors 4ES BP EXPLORATION (AK) Keith Lopez Well Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • ao Re: Milne Point Field, Schrader Bluff Oil Pool, MPE-13BLS Sundry Number: 310-267 Dear Mr. Lopez: ~ ~ ' - ~ v Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ ~ day of August, 2010. Encl. U ~,~ ~ ~,~-~~10 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ APPLICATION FOR SUNDRY APPROVALS ~n aac 25.2an 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate0 ' Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate0 Alter Casing ^ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 202-0440 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service Q_ 6. API Number: Anchorage, AK 99519-6612 50-029-22536-02-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPE-136LS © Spacing Exception Required? Yes ^ No 9. Property Designation (Lease Number): 10. Field/Pool(s): _ ADLO-047437 0025518., MILNE POINT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8852 4438.33 - 8765 - 4414.56 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# H-40 SURFACE 112 SURFACE 112 1490 470 Surface 2475 13-3/8" 68# L-80 SURFACE 2506 SURFACE 2445 5020 2270 intermediate 2476 9-5/8" 40# L-80 SURFACE 2506 SURFACE 2445 6870 4760 Production 8819 7" 26# L-80 SURFACE 8850 SURFACE 4438 7240 5410 Liner Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - LS 2-3/8" 4.7# L-80 URFACI 8651 Packers and SSSV Tvoe: 7"X2-3/8" BAKER GT RET DUAL PKR Packers and SSSV MD and TVD fftl: 8160 4242 7"X2-3/8" BAKER FH RET PKR 8631 4378 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/31/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ~- GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact KEITH LOPEZ Printed Name KEITH LOPEZ Title WELL ENGINEER Phone Date Signature ~ 564-5718 8/24/2010 Prepared by Gary Prebie 564-4944 COMMISSION USE ONLY Number: 3i ~ ~~ Sund it ~ ry ness Conditions of approval: Notify Commission so that a representative may w V Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ 2010 +O~issi Subsequent Form Required: ~ ~ - Lf D 1 .~~"'~' ~~ APPROVED BY ~( /( ~~ ~ ~ L Approved by: COMMISSIONER THE COMMISSION Date: C> (. ~ y ~~~) 1J ~ ~ V I 1 Y ~ L (/ Y L~.ro ~Z3//O ( Submit in Duplicate MPE-136 202-044 PERF OTTOI:HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Bas MPE-13B 4125/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-13B 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-136LS 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-136LS 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-13B 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 MPE-136SS 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVE SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i by • To: Mark O'Malley/Nathan Leonard Date: August 24, 2010 MPU Well Operations Supervisor From: Keith Lopez, MPU Schrader Pad Engineer 907-564-5718 Subject: MPE-13BLS Coil Cleanout, Re-pert and Acidize Step Unit Operation 1 C Conduct coil Cleanout of wellbore 2 C Re-perforate and acidize as necessary OBJECTIVE 1. Cleanout wellbore with coil tubing post MBE treatment. Re-perforate and acidize as necessary to regain injectivity. PROCEDURE Cleanout 1. RU, hold pre-job safety meeting, PT 2. RIH and Cleanout wellbore with coil tubing to TD. 3. Perform injectivity test with produced water. Contingency if injectivity is not regained 4. RIH and re-perforate the same depths with coil perforating guns. ~ 5. Perform injectivity test with produced water. ~ 6. Spot 5 bbls of 7% HCI and soak perfs. ~ 7. Perform injectivity test with produced water raising injection pressure to a max of 3000 psig if - necessary. ,- S 1 Tree: CI4V 21116' SM Dual string " ~ ^ _ 1 ~ ~' YYdlhead:91' x 231'8' 5M FMC dual string m t Hanger thread 2 3J8" Et1E top ared TGIt Btm. r Ctw-H 8PV pn~e 20". 91.1#, H~19, Welded 112' 13 3ff1", 68 # L-BQ. BTC 5193' 9'S/8' 4U#. L-~41D. It3T t'AOD 12835' Short Strirtts 2859' 2-348" HES X-Nipple (1.875" Pk9- ~) 7' 26#, L-811, BT MC7[a Casing (drift id = 6.151, cap.= .0383 bpfj 2-3d8". 4.7 #!fl L-80, TC-11 tubing (dr4t id = 9.9111, cap =.A0387 bpf) 8919' 218' HES X-Nipple [1.875' pkg. bore) 8189' 2-318' HES XN-tlipple {1.875' pk¢ btm Mo-Gcr 1.791' 8175' Tuareg Lsil 1 WLEG See Spf Interval (T1+'I}) 2' P,1 6 8195' -8225' 4252' - 4Z'9?' 2' Pd 4 8660'-8480' 4384" -4391' 2' PJ 4 8720' -8741)' 4402' -4407' 8785' 7' Halliburinn Float Cellar PBTD ~ ~~ 7' H rGcm float shoe DATE REV. BY COI4MENTS 4106102 Mfll7 Sidetrack Completion Nabors 27E 4124102 MDO Add pens w CTtI - E-line 911184 Lee Hutme Remn+plebe as dual -Nabors 4E5 baba: 7° palt~ Is ~ntls~ 'BST wtpe Lont7 Strinst 2-318' HE5 X-Nipple (1.815" pRg. bore) 2968' 2-348` HE5 X-Nipple {1.875' pkg. bore) 8118• 7' x 2-3f8" Saker'CaT' t2et dui Ptr 8#~' 1.9+15' ID. T x 2-318' t#aker'FH' Ret Pkr 8839' 2.49' 1l]! Z 318' HES 7(N-N~ple X1.8}~ fig, ) 86#3' No-Go 1.799' 2-318` Bater'E" Hyrdro Trip Sub 8651' wr 6` rrraiesteoe pup {baltom depMrp (1-~" Pk9~ ~) Hydro Trip Sub ELMC1 864T MILNE PAINT UNIT WELL Nor.: MPE-131~i AFI • 511-029-225~4'i-0~ BP EXPLt)RATtUN {AK} t?rig_ K8 Elev. =59.0' (Doyon 14) Orig. H~ Etev. =30.55' (Doyora 14) u ~~Q~~ 0~ Q~Q~~Q /,~,...E..~o~w.~ Keith Lopez A .~ ~ ~ ~~ra t~~ Wells Engineer ;,~:,`~?~~~` ~~~~'v •1 '" BP Exploration (Alaska), Inc. _ D ~.~,' ~" P.O. Box 196612 ~ (~~` __--- Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Pool, MPE-13BLS Sundry Number: 310-247 Dear Mr. Lopez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~~Jday of August, 2010. Encl. STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrili ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: MBE REPAIR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 202-0440 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22536-02-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ^ MPE-136LS Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-047437'0025518 ' MILNE POINT Field / SCHRADER BLUFF Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8852 4438.33 8765 4414.56 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 91.1# H-40 SURFACE 112 SURFACE 112 1490 470 Surtace 2475 13-3/8" 68# L-80 SURFACE 2506 SURFACE 2445 5020 2270 Intermediate 2476 9-5/8" 40# L-80 SURFACE 2506 SURFACE 2445 6870 4760 Production 8819 7" 26# L-80 SURFACE 8850 SURFACE 4438 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - LS 2-3/8" 4.7# L-80 URFACI 8651 Packers and SSSV Tvoe: 7"X2-3/8" BAKER GT RET DUAL PKR Packers and SSSV MD and ND tft): 8160 4242 7"X2-3/8" BAKER FH RET PKR 8631 4378 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/17/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^~ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact KEITH LOPEZ Printed Name KEITH LOPEZ Title WELL ENGINEER Signature Phone Date 564-5718 8/10/2010 Prepared by Gary Preb-e 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:~j ~ "~~ ' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ~ ~'~• ~ ~~ Other: LU I't.s ~' :`~~~ to ~# ~ise ~ ~'iM~l'lISSI Subsequent Form Required: ~ 0 _ [Z/~Y • u ' ~*+~~it~l :9Q~ APPROVED BY Approved by: COMMISSIONER THE COMMIS ION Date: S // 1 Q R i C~ I ~3„t ~,3 ~~ ~~ ~ . ;~~,~ I~~~1~dS AUG 1.6 Z0~ ` ~~0 Form 10-403 Revise ~ Submit i at MPE-13B 202-044 PFRF ATTO[_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Bas MPE-13B 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-13B 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-13BLS 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-13BLS 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-13B 6117/04 APF 8,195. 8,225. 4,252.94 4,262.56 MPE-136SS 6117/04 APF 8,195. 8,225. 4,252.94 4,262.56 AB ABANDONED PER PERF APF ADD PFRF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVE SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • r~ u by To: Mark O'Malley/Nathan Leonard MPU Well Operations Supervisor Date: August 9, 2010 From: Keith Lopez, MPU Schrader Pad Engineer Subject: MPE-13BLS MBE Treatment 907-564-5718 Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPE-13BLS. 2 F Bullhead treatment down MPE-13BLS OB sand . Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returnin to production. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. , CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. ~ i Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre-flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre-flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 10. Forward all post job assessments (w/all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. Tree: CI'N 2 1.16° _`~h1 Oual string 'uVellhead:ll' x 2 3a'2' Shi FhfC dual string ~ ~ ~ ~ ~ ,~ Hanger threat 2 3+'?' EJE tc#? art TC-1 Bim. 2' CISrS-#-s 9P1Y prsaf=e i0', 81.1#, H~Q, Welded 1 ?~' 13 lj8", 68 # L-80,13TC 5193' 9 b18` 40#. t.-t~, t13T h9C}D 1?83°~' Short S#rina ~~,,2. 2-318' FIE.:{-Ni4e ?.3?F" pkg. btrre~ 7" 26~, L-8Q, IBT AAQD Casing Idrift ir1= 6.151. ;.ap = .0383 bpf) 2-3'8' 4.7 #.`R L-80.. TG-I ;ubi~^g i;drft id = 1.u~01, cap.=.0387 bpf;i 8119' 2-3~E° -IES X-Nipple f 1.E~75° pkg. borer 8149' 2-3+`8' HES X@W-Nple (t.E75' p<kg~ +r Nc~:~ 1 ?9*` 8175' Tubing tail; WLEG P~rforatic+rr Summary 765' ?" Halliburton Fx~at C~Ilar FBTO m •850' T Ha 5urtr3n float shce DATE F#ESJ. EiY CG7Mh7EA1T8 4106"°02 MOt7 S:zwetrack~ `.omplezion Nab~rrs 2? 4d24~'02 htr~Cl ~cc perfs w CTU - E-line S;' 1~t?4 Lee Hai me Recorr~k:te as coal -Labors 4ES tltst8: 7~ caaing Ia Ientl~ fNl ry elm Lonsi Strin~l -3J8` HE'S X Nipper t1.8?5` pkg. bcr~;i 2968' 2-S'8` HIES }€NiPPIe ..8'S' pkg. bcrel S tt6' '° x 2_3~=~' Baker'GT' Re*.. dual f kr x:160' L45' 10. 7" x 2-31£" &akes'=H R:et. ='kr ~~31' 2.4t'iD. 2-3a`?.• tiES :~fw-N pPle i1.~.?5° Pkg. tarej fi643° Nc=tea ' .7g 1° 2-?r'8` Baker E' Hyrko "rip Sub w.' 6' rz~>esa^~Qe prsp t5oteorn death; 8681:,. (1:27' pkg_ t~irej Hydra Tipp Sut1 ELMD 86~?' MILNE Pt?INT UNIT V4'ELL Ne.: 141PE-13B API : 50-02J-22536-D2 BP EXRLaRQT~IQN ~AK~ t7rig. FCB Elev.. = 58.0` [Csoya~n 14) ~rig~ H8r Elev. = 31755' ~Cro~+an 1~} ~~! KARL AND GAS CON ERVAT ON COMMISS~ q~QQF~jpOF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 MBE REPAIR Performed: Alter ~~t~6~i~, Perforate New Pool ^ Waiver^ Time Extension ^ ~ ~ ~ `~~" Change Approved Program ^ 6itdown ^ Perforate ^ Re-enter Suspended Well ^ ' ' `" 2. Operator BP Exploration (Alaska), Inc. 4. WeII Class Before Work: Permit to Drill Number: Name: Development ^ Exploratory ^ 202-044 0 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-22536-02-00 8. Property Designation (Lease Number) : ~ ~~ 9. Well Name and tuber: ADLO-047437 40 5 ~ K't3 ~ +~ MPE-13B LONG STRING 10. Field/Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 8852 feet Plugs (measured) None feet true vertical 4438.33 feet Junk (measured) None feet Effective Depth measured 8765 feet Packer (measured) 8160 8631 true vertical 4414.56 feet (true vertical) 4242 4378 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.1# H-40 SURFACE - 112 SURFACE - 112 1490 470 Surface 5193 13-3/8" 68# L-80 SURFACE - 5193 SURFACE - 3455 5020 2270 Intermediate 2476 9-5/8" 40# L-80 SURFACE - 2506 SURFACE - 2506 6870 4760 Production 8819 7" 26# L-80 SURFACE - 8819 SURFACE - 4429 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 2-3/8" 4.7# L-80 28 - 8651 28 - 4383 Packers and SSSV (type, measured and true vertical depth) 7"X2-3/8" BAKER GT RET. DUAL PKR 8160 4242 7"X2-3/8" BAKER FH RET. PKR 8631 4378 12. Stimulation or cement squeeze summary: Intervals treated (measured): ti ~ ;b- ,; r ~(, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 340 421 Subsequent to operation: 495 1012 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^~ SPLUG ^ 17. I hereby certity that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-385 Contact Gary Preble Printed Name Gary Pr le Title Data Management Engineer Signature Phone 564-4944 Date 4/12/2010 ~..~~~.~~~ Iwo ay nn v iyn~ai vnry RBDMS APR 132010 ~~. i3.id .~~ ~, ~~.,~/~o MPE-13B 202-044 o~nC ATTAl~IJ11ACAIT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Bas MPE-13B 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-13B 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-13BLS 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-13BLS 4/25102 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-13B 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 MPE-13BSS 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVE SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE u • MPE-13B (LONG STRING) DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/2/2010,T/I/0=1000SS800LS/0/100/0 Freeze protect Tbg and Flowline. Pump 13 bbls X60/40 down SS Tbg. Pump 3 bbls 60/40 meth down SS flowline. Pump 13 bbls 60/40 meth down LS Tbg. Pump 3 bbls 60/40 meth down LS flowline. FWHP=1100SS925LS/0/0/0. Swabs, Wings, Ssv closed. Mst., IA, OA, OOA ~ open. Hang freeze protect tags, notify operator valve position. 4/3/2010 HES pump truck #10297812, Pump LS H2ZER0 LT Polymer WSO: :.Pump 50 bbl's PW pre-flush. Swap to H2ZER0 polymer, pumped 193 bbl's at `average once polymer reached perfs = 1021 psi / @ 0.46 bpm <'"'"`Job continued 4/4/10*** 4/4/2010Continue from 04 03-10. Pump LS H2ZER0 LT Polymer WSO: ?Pump total of 410 bbl's H2ZER0 polymer treatment, 55 bbl PW & 15 bbl 60/40 meth over flush. "" ***Job Complete*** FLUIDS PUMPED BBLS 110 PW 47 60/40 METH 410 FDP-S835 H2ZER0 POLYMER 270 3% KCL 28 HZ-20 LINKER 879 Total Tree: CIW 2 1/16" 5M Dual string Wellhead:1 l" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" EUE top and TC-II Btm. 2" CIW-H BPV profile 20", 91.1#, H-40, Welded 112` 13 3/8", 68,# L-80, BTC 5193' 9 5/8" 40#, L-80, IBT MOD 1283: Short Strina 2959' 2-3/8" HES X-Nipple (1.875" pb KOP @ 1100` Max. hole angle = 77 deg @ 4340 Hole angle thru perfs = 74 deg 7" 26#, L-80, IBT MOD Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8", 4.7 #/ft L-80, TC-II tubing (drift id = 1.901, cap.=.00387 bpf) 8119' 2-3/8" HES X-Nipple (1.875" pk 8169' 2-3/8" HES XN-Nipple (1.875" p No-Go 8175' Tubing tail / WLEG Perforation Summary Size Spf Interval (T\ 2" PJ 6 8195' -8225' 4252' - 4; 2" PJ 4 8660' -8680' 4384' - 4 2" PJ 4 8720' -8740' 4402' - 4~ 8765' 7" Halliburton Float Collar PBT[ 8850` 7" Halliburton float shoe DATE REV. BY COMMENTS 4/06/02 MDO Sidetrack Completion Nabors 27E 4/24/02 MDO Add perfs w CTU - E-line 9/1/04 Lee Hulme Recomplete as dual -Nabors 4ES Orig. KB 21!•G. = 59.0' (Doyon 14) Orig. Hgr Elev. = 30.55` (Doyon 14) Note: 7" casing is landed on emergency slips iES X-Nipple (1.875" pkg. bore) 2966` Vell was sidetracked 3/27/02. Window il 2506' - 2522' . 7" casing was run trough window to the surface. Old hoe depth 5193' 1ES X-Nipple (1.875" pkg. bore) 8116` 3/8" Baker'GT' Ret. dual Pkr 8160' ' I ID. 3/8" Baker'FH' Ret. Pkr 8631' ~. -IES XN-Nipple (1.875" pkg. bore) 8643' No-Go 1.791" Baker `E' Hydro Trip Sub 8651' iuleshoe pup (bottom depth) pkg. bore) Hydro Trip Sub ELMD 8647` '5" ball. MILNE POINT UNIT WELL No.: MPE-136i API : 50-029-22536-02 BP EXPLORATION (AK) MPE-13Bi FW: Epsom Salt Tracer on MPE-SLS to MPE-20A---WORKED PERFF~--Bad Ne... Page 1 of 3 Maunder, Thomas E (DOA) From: Longden, Kaity [Kaity.Longden@BP.com] Sent: Wednesday, March 31, 2010 10:38 AM To: Maunder, Thomas E (DOA); Roby, David S (DOA) Subject: FW: Epsom Salt Tracer o MPE-136LS oMPE-20A---WORKED PERFETLY--Bad News is 85-90% of the tracer was Immediat recovered. Good Morning Tom and Dave, We have completed the first Epsom Salt tracer test from MPE-13BLS to MPE-20A with great success. Below are the analyzed results, done by Bradley Brice, for your records. We plan on redoing this surveillance sometime next month as well as another pair of wells coming sometime this summer (MPI-10 to MPI-06). Please let me know if you need anything else. Thanks, Kaity Longden Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT The Epsom Salt tracer on MPE-136LS to MPE-20A was performed on 3/24!2010. Epsom Salt and Red Dye were added to 35 bbls of injection water to use as a tracer for evaluation of the water breakthrough. By using a material balance using both the Magnesium and Sulfate (which is the composition of Epsom Salt) there is a check on the tracer. Between 85% and 90% of the injected 35 bbls of water tracer into MPE-13BLS showed up at the Producer MPE- 20A in 3 1/2 hours after the injection. The following graphs shows the agreement of the two tracers. It is possible that the double peak of the tracer indicates that there is more than one direct route connecting the Injector (MPE-13BLS) and Producer (MPE-20A). FW: Epsom Salt Tracer on MPE-~LS to MPE-20A---WORKED PERFI~Y--Bad Ne... Page 2 of 3 ~ Magnesium MPE-20B Tracer R.rrival -~- sulfate (Tracer Injected into MPE-13BLS) 250 c Z00 ~ 150 c 0 c...y 100 .~ ~ 5a 0 3124110 19:00 soo 500 d00 ~ 0 30D 200 ~ c 100 t° m 0 -100 31251'10 0:00 Following is a graph showing when the Tracer was Injected into MPE-136LS and how it arrived at Producer MPE- 20A. Note that the scale on the right normalized the Recovery of tracer to 100% of the Injected Tracer Volume: +Tracer Injection ~ MPE-13BLS MPE-13BLS to MPE~OB ~ Tracer (Magnesium) Recorrery@ MPE,20B Epson SaltTracer3l24l~010 Tracer (Sulfated Itecoriery MPE,20B L O 35.4 31.5 28.0 24.5 21.0 17.5 14.0 10.5 7.4 3.5 4.0 1A ~ 09 ~ aS ~ 0.7 oe: 0~6 ~ 4.5 " 4A ~ 4A ~ 42 ~ 4.1 0 4A ~ w a ~ c g V o V H w 0 m p~~ p p~ p~~ p ~~ a~ ~ p~ O O G Ct ~ 4 4 4 4 4 ~ ~ ~ ~4 ~4 ~O ~4 ~O ~~ O 4 4 try ~~ M~ M~ ~~ ~~ M~ ~ ~ ~~~ ~~ M M M The Fleld did a really GREAT job in getting a uniform mixture of the tracer, and the sampling. And the NSK Lab did a GREAT job in their analysis. 3/31/2010 3~2d/10 312d/10 312d110 312d/10 20:00 21 ~0 22:00 23:00 ~J Maunder, Thomas E (DOA) From: Longden, Kaity [Kaity.Longden@BP.com] Sent: Friday, March 19, 2010 4:45 PM To: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Tom- • Page 1 of This well is comingled downhole so we have no true way of monitoring one or the other. We will be taking the samples at surface. Technically, we will be injecting the tracer into the LS of MPE-136 which is completed in the OA sand so we expect that the magnesium we see will be coming from the mother bore (MPE-20A) which is the lateral in the OA sand. Hope this helps. Kaity Longden Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 19, 2010 4:28 PM To: Longden, Kaity Cc: Roby, David S (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Thanks Kaity. One question ... will you be monitoring the mother bore (MPE-20A) as well as the lateral (MPE- 20AL1)for increased Mg++? _ Tom Maunder, PE ~Q ~ ~ aCl q~'~,,,, ~C~w-t~5 5 AOGCC From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Friday, March 19, 2010 2:53 PM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA) ~~ ~O~l Subject: RE: Question on Milne Point Schrader Bluff Injection Orders T ~-OSy Thanks Tom for the response. We are planning to first try this tracer test on MPE-13BLS to MPE-20A late next week. We will then re-do the test on those wells following an MBE treatment in April. The next set of wells for the Epsom Salt tracer test will be MPI-10 to MPI-06 sometime early summer this year. I would be happy to send you updates on our findings as we ge~the information Kaity Longden a.~j_ ~p C1 `~.~ _ ~c~5 Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 19, 2010 9:00 AM To: Longden, Kaity Cc: Roby, David S (DOA) 3/22/2010 Page 2 of ~ ~ Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Kaity, Dave's interpretation is correct. By adding the Epson salt to the produced water you are creating the tracer fluid. Tracer fluids are clearly allowed by the injection order. Good luck with the trial. As the fluid movement information is quantified, we would appreciate a communication indicating the findings. Also, can you identify the possible candidate injection wells? Call or message with any questions. I will place a copy of this message in the Order file. Tom Maunder, PE AOGCC From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Wednesday, March 17, 2010 4:31 PM To: Roby, David S (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders Sounds good Dave. Thanks for taking the time to make sure we have our bases covered. Kaity Longden Pad Engineer Milne Point Viscous Oil Team BP Alaska ACT 564-5554 From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, March 17, 2010 4:22 PM To: Longden, Kaity Cc: Maunder, Thomas E (DOA) Subject: RE: Question on Milne Point Schrader Bluff Injection Orders I would say your interpretation of the rule is correct but I would like for Tom Maunder, our UIC program manager, to weigh in on this to make sure I'm not missing something. Dave Roby (907)793-1232 From: Longden, Kaity [mailto:Kaity.Longden@BP.com] Sent: Wednesday, March 17, 2010 3:33 PM To: Roby, David S (DOA) Subject: Question on Milne Point Schrader Bluff Injection Orders Good Afternoon Dave, I was talking with Mike Bill here at BP yesterday about a tracer study we are looking to do here in the near future. We are looking to quantify the amount of injection water being cycled between injector and producer pre and post MBE treatment in order to judge success. In order to do this we will be increasing the Magnesium concentration in our normal produced water (by adding Epsom Salt) and injecting it in an injector while monitoring the concentration of Magnesium on the producer side. This will allow us to see what percentage of injected water is cycling directly through. We expect the tracer to come through in less than 6 hours. I believe this kind of study is authorized under the Area Injection Order No 10B, Part B: Schrader Bluff Oil Pool Authorized Fluids, section C) tracer survey fluid to monitor reservoir performance. Mike suggested that I confer with you prior to the job to make sure we do not need any additional notifications. Thank you in advance for your help on this. If you need addition information please write back or call my office 3/22/2010 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO►USSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ms. Kaity Longden Staff Geologist BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit Field, Schrader Bluff Pool, MPE- 13BLS Sundry Number: 309-385 Dear Ms. Longden: 0, L- .' N f' D F 1 1 8 ZOOS Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 ne 0 Orman n om i s s Z r DATED this& day of November, 2009 Encl. „� STATE OF ALASKA ��`�� I 1 ALASNOIL AND GAS CONSERVATION COMMIS NOV 1 6 2009 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Oil & Gas Cons I SI0t1 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Re -enter Suspend0 ft Alter casing E] Repair well ❑ Plug Perforations ❑ Stimulate ❑ Other Q Specify: O BE Repair - Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -0440 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22536 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes El No El MPE -136LS 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 047437 Milne Point Unit Field / Schrader Bluff Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8852 4438.33 8765 4414.56 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20 "91.1# H -40 Surface 112 Surface 112 1490 470 Surface 2475 13-3/8'68# L -80 Surface 2506 Surface 2445 5020 2270 Intermediate 2476 9 -5/8" 40# L -80 Surface 2506 Surface 2445 6870 4760 Production 8819 7” 26# L -80 Surface 8850 Surface 4438 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: SS 2 -3/8" 4.7# Tubing Grade: L -80 Tubing MD (ft): Surface -8175' SEE ATTACHED - - LS 2 -3/8" 4.7# L -80 Surface - 8651' Packers and SSSV TVDe: 7 "x2 -3/8" Baker GT Rat Dual PKR Packers and SSSV MD and TVD (ft): 8160' 4242' 7 "x2 -3/8" Baker FH Rat PKR 8631' 4378' 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q ' 14, Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/30/2009 Oil ❑ Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ Q GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kaity Longden Printed Name Kaity Longden Title Staff Geologist Signature Phone Date 564 -4531 11/16/2009 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ �(�ti�� /�1S ,`e Ilk Other: Subsequent Form Required: y , s � APPROVED BY Approved by: 4C OMMISSIONER THE COMMISSION Date: N A L �`�� °s Form 10 -403 Revised 07/2009 Submit in Duplicate MPE -13BLS 202 -044 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPE -13B 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE -13B 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE -13B 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 MPE -13BLS 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE -13BLS 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE -13BSS 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • by 0 To: Mark O'Malley /Jerry Sharp Date: November 13, 2009 MPU Well Operations Supervisor From: Jack Lau, Wells Engineer 227 -2760 Kaity Longden, MPU Schrader -E Pad Engineer Subject: MPE -13BLS Gel Job Step Unit Operation 1 O Shut in all offset producers and other injector string. Bullhead water into MPE - 13BLS. 2 O Bullhead gel treatment down MPE- 13131-S. Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returning to production. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a rigid gel. Measure of success 1. Gel treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant gel per guidance from the Environmental Team. PROCEDURE Stagel. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure other injector string and offset producers are SI 3. Spear in with Methanol, follow with produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. High Volume Gel Treatment 5. Ensure other injector string and offset producers are off line 6. Pump produced water preflush, follow with gel treatment and produced water over flush, then freeze protect. 7. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 8. Rig down all equipment and hold post -job assessment meeting to capture learnings to be incorporated into future jobs. 9. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. Wellr e W: 2,i i' a? 816' Dual 6U99g MP E — 1 3B Ka E*v. - 59.0` (iDnydn 14) Wellhad: Sr Fi4t F11QC r»iaC ' {21v H BPV 2 3W ELIE by and TC4184n. Orfg tigr El eu- - 30.85' (Doyon 14) 2 2' A pluft 20'. 9118, HdO, Welded 112 NOW 7■ ashy is hn/N m 13 W Kip L-w, BTC 5143' 9 &Ir 4W, 1--90, 43T MW 12835' Short String Lona S trina 0 2 318' HES X -NWe (1.975 ptg. bate) 2 -atT HES X -41pple q 1875 ple} bore) 2966 KOP Q 1100' Max_ We angle - r deg Q 4340' well was Wleracked 3tZ7(02. Wndm Mole angle thru pens - 74 deg 1§ 2505'-25=. T using ryas ne► OUgn wB'*W 1D the SWUM Old Slice depth 519Y T 26#, L-M IST MOD Oastng (do k1 - 6.151, cap.-.am by n 2-M', 4.7" L-W, TC41luting {drdd ld - 1.-01, cap. - A4367 bpi) 2 -3 HES X - Nppte (1:975 ptg. bare) 2.3V 1-1_S X4appte (1.875- Peg. =e) 8116' F1 H_J 7' x 2-3+8' Baser'GT' Ret. CUM Ply 8140 8169 2-W HES X +tipple (1.875 pLq. bore) NO 1.7'91' 8175 Mbtngtad?WLEG Perforation Sum mary T x 2 -3W Baker FK P&L Pkt �F 2A1' ID. Srze Sp1 brtenral t'T�1 m 7 (1.9T 04 fie) 2-YT HES )Wdipple (1.V pkg. bate) 2' RI 6 8195' 25 -82 4253' - 4262 NO-Go 1.7'31 660 ' 2' Pi 4 8 -8680' 43M - 4391' r RI 4 8=4740' 4407-4407 2-Yr Baker 'E' Myffo Trip Sub io v =w6tDa pp (Dotbom depm) 5651' Hydro Trip Sub ELM© 9647' 8765? 7` Ha)>btstGh Fbat PBTD d 1.7a taar, 8851Y , hlaflbllrkxlllaa�6lece DATE REV. BY COMMENTS 40602 MDO Sme'aMCWVe WNabtxs27E MILNE POINT UNIT WELL No_: MPE -O i 4=02 MDO Add p" w CTU - 541ne API : 50 -029- 22536-02 91144 Lee fnitrle * a6 dual - Nab 4ES 8P EXPLORATION (AK) STATE OF ALASKA ~~~ 20~~ ALA OIL AND GAS CONSERVATION CO REPORT OF SUNDRY WELL~~Q~~Sir~~issian ~2~ .3-/a?o9 1. Operations Abandon ~ Repair Well Q _ Plug Perforations ~ Stimulat~~0~age; Other ~ POLYMER Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ TREATMENT - Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~ 202-0440 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-29-22536-02-00 • 7. KB Elevation (ft); 9. Well Name and Number: 59 KB MPE-136L`~-L~fja ej~'~'r '~ 8. Property Designation: 10. Field/Pool(s): ADLO-047437 ~QLOOa,~J'/ f'' _ MILNE POINT UNIT Field/ SCHRADER BLUFF Pool 11. Present Well Condition Summary: Total Depth measured 8852 - feet Plugs (measured) None true vertical 4438.33 - feet Junk (measured) None ^r ry f. i Effective Depth measured 8765 - feet " ; ~. ~~'~ z, ~~~,~ '" ~',;° true vertical 4414.56 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.1# H-40 Surface - 112 Surface - 112 1490 470 Surface 2475 13-3/8"68# L-80 Surface - 2506 Surface - 2445 5020 2260 Intermediate 2476 9-5/8" 40# L-80 Surface - 2506 Surface - 2445 6870 4760 Production 8819 7" 26# L-80 Surface - 8850 Surface - 4438 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) LONG 2-3/8" 4.7# L-80 SURFACE - 8651' SHORT 2-3/8" 4.7# L-80 SURFACE - 8175' " " " " ' Packers and SSSV (type and measured depth) 7 X2-3/8 BAKER GT RET DUAL PKR 8160 7"X2-3/8" BAKER "FH" RET PKR 8631' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 394 900 Subsequent to operation: 358 909 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory r Development C` Service ~ ICE'' Daily Report of Well Operations X 16. Well Status after proposed work: Oil I~ Gas ~ WAG ~ GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date 3/11/2009 Form 10-404 F~vised 04/2006 ;:;~~~~, ~, af~*i ~ ~~ ?~~~ ~3 f(~ Submit Original Only MPE-13B 202-044 PFRF OTTOCHMFNT • Sw Name Operation Da Perf Oper Meas Dep Meas Dep Tvd Dept Tvd Depth Base MPE-13B 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-136 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-13B 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 MPE-13BLS 4/25/02 PER 8,660. 8,680. 4,385.87 4,391.35 MPE-13BLS 4/25/02 PER 8,720. 8,740. 4,402.3 4,407.75 MPE-13BSS 6/17/04 APF 8,195. 8,225. 4,252.94 4,262.56 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOV ED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATE SQZ SQUEEZE MIS MECHANICAL ISOLATE STC STRADDLE PACK, C LOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE L~ MPE-13BLS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 3/3/2009Freeze protect LS T/I/0=600/60/40/180/0 Pump 20 bbls 60/40 down LS. FWHP's=1000/240/0/180/0 SV, SSV, WV=s/i MV=o all annulus valves=OTG 3/3/2009 Pump H2Zero LT Polymer. (Post Thermatek Treatment). MIRU HES pumping service. Hold PJSM and PT. Pumped 229 bbls of H2Zero LT Polymer;and displaced with 61 bbls of produced water. LRS moved in and freeze protected '; with 20 bbls of 60/40 methanoLAll fluids pum^~~ ~~~~~~~ ~+ _ ~ ti.,.,, _„nn .,~, Completed pumping, RD and MOL. FLUIDS PUMPED BBLS 20 60/40 METH 229 H2ZER0 249 Total • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, January 12, 2009 9:09 AM To: 'Preble, Gary 6 (SAIC)' Cc: Igbokwe, Chidiebere Subject: RE: MPE-13B LS polymer WSO ~~ ~ _ ~ l..a .- Page 1 of 1 Gary and Chidi, The only paperwork needed is the 404. We are interested in activities dealing with MBEs. At some time in the future, it may be appropriate to have a meeting to discuss them and attempts to remedy them. Tom Maunder, PE AOGCC ~_. .. __.... .... From: Preble, Gary B {SAIC) [mailto:Gary.Preble@bp.com] Sent: Monday, January 05, 2009 10:34 AM To: Maunder, Thomas E (DOA) Cc: Igbokwe, Chidiebere ia~y~~ ,jA~ _ ~~ Subject: FW: MPE-13B LS ploymer WSO Tom, Is there any Sundries needed for Chidi's proposed work below? From: Igbokwe, Chidiebere Sent: Monday, January 05, 2009 10:11 AM To: Preble, Gary B (SAIC) Cc: Boccardo, Giovanna; Emembolu, Emeka; Sauve, Mark A; Rupert, C. Ryan Subject: MPE-136 LS ploymer WSO Hi Gary, We did a Thermatek job to remediate a matrix by pass event (MBE) on MPE-13B LS (injector) in 2008 and we are moving forward to perform a polymer job to fill the void around the thematek plug hence shut off direct water response from the injector to the producer. Pardon me but without knowing your level of familiarity about the MBE's, it basically is a phenomenon where we see direct response between the injector and the producer with a catastrophic water breakthrough from injector to producer that is identified by a raped increase in infectivity on the injector (with WHIP dropping off) corresponding with rapid increase in the producer BHP which hurts overall recovery. I believe you get the emails when we send out wellworks but just wanted to check-in with you to verify if there are any state reporting requirements that goes with this job or any future jobs we will be doing to remediate MBE's as well as relative permeability modification out at MPU? Please advice accordingly. Best Regards, Chidi Igbokwe 907-564-4795 1/12/2009 MEM®RANDUM • TO: Jim Regg ~ ,, t ~ ~,~~,~~ o~ P.I. Supervisor`~`~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 15, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-13B MILNE PT UNIT SB E-13B Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv --S Comm Well Name: MILNE PT UNIT SB E-13B Insp Num: mitCS081014193216 Rel Insp Num: API Well Number: 50-029-22536-02-00 Permit Number 202-044-0 ~ Inspector Name: Chuck Scheve Inspection Date• ton4i2oos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-13B (Type Inj. ~ ~' TVD azaz ''~ IA to zzzo z16o j z16o P T. , zozoaao ~TypeTest I sPT ;Test psi Isoo / OA lao 3~0 !I zao ~ 20o i I Interval avRTST p/F P ' Tubing logo logo logo i Io~o I ~ Notes: Pretest pressures observed and found stab]e . Well demonstrated good mechanical. integrity. '~ ~,. '~ ~ Ep f~~ f, rFh k. Wednesday, October 15, 2008 Page 1 of 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) MEMORANDUM TO: Jim Regg '\? ,0\ ZlÓt04 P.I. Supervisor h~l FROM: Chuck Scheve Petroleum Inspector Well Name: MILNE PT UNIT SB £-13B Insp Num: mitCS041 024163456 ReI Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 27,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-13B MILNE PT UNIT SB E-13B jo~~ oLt-tr Src: Inspector Reviewed By: P.I. Suprv :S13~ Comm NON-CONFIDENTIAL API Well Number: 50-029-22536-02-00 Permit Number: 202-044-0 Inspector Name: Chuck Scheve Inspection Date: 10/24/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-13B Type Inj. P TVD 4242 IA 1380 2500 2460 2460 P.T. 2020440 TypeTest SPT Test psi 1060.5 OA 280 400 400 400 Interval WRKOVR P/F P Tubing 900 900 900 900 Notes: Pretest pressures observed for 30+ minutes and found stable. Well was recently recompleted with dual tubing strings. Wednesday, October 27,2004 SCANNED NOV 0 9 2004 Page 1 of 1 ~ STATE OF ALASKA ~ ALASKA L AND GAS CONSERVATION CO. AISSION REPORT OF SUNDRY WELL OPERATION~ECEIVíZíJ 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 59.0' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 8. Property Designation: ADL 047437 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 2475' Intermediate 2476' Production 8819' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Con 0 Repair Well 0 Plug Perforations 0 Stimulate III Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic III Service 202-044 6. API Number: 50-029-22536-02-00 8852 4438 8765 4415 9. Well Name and Number: MPE-13Bi 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 13-3/8" 2506' 2445' 5020 2270 9-5/8" 2506' 2445' 6870 4760 7" 8850' 4438' 7240 5410 8195' - 8740' 4253' - 4408' Long 2-3/8", 4.7# Short 2-3/8",4.7# 7" x 2-3/8" Baker 'GT' Ret Dual Packer 7" x 2-3/8" Baker 'FH' Ret Packer L-80 L-80 8651' 8175' 8160' 8631' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ;"'i! > '.t ~ ~rP 't 'i \..) .. 13. ¡I-Bbl Tubin Pressure Avera e Production or In'ection Data Water-Bbl Casin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run III Daily Report of Well Operations III Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 0 Development III Service 16. Well Status after proposed work: 0 Oil 0 Gas 0 WAG 0 GINJ III WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: 304-274 17. Printed Name Sondra Stewman Title Technical Assistant r-- Prepared By Name/Number: Sondra Stewman, 564-4750 Submit Original Only Tree: CIW 2 1/16" 5M Dual str Wellhead: 11" x 23/8" 5M FMC __dl string Hanger thread 2 3/8" EUE top and TC-II Btm. 2" CIW-H BPV profile 20",91.1#,H-40,Welded D!Ð IÐP ø+ W'f\d..clO 133/8",68,# L-80, BTC ~ I &193' I TI:)Ç> 4P-t: 'vJ.1~ 95/8" 40#, L-80, IBT MOQZsoc..'~ Short Strine I 2959' I 2-3/8" HES X-Nipple (1.875" pkg. bore) KOP @ 1100' Max. hole angle = 77 deg @ 4340' Hole angle thru perfs = 74 deg 7" 26#, L-80, IBT MOD Casing (drift id = 6.151, cap.= .0383 bpf) 2-3/8",4.7 #/ft L-80, TC-II tubing (drift id = 1.901, cap.=.00387 bpf) ~ 2-3/8" HES X-Nipple (1.875" pkg. bore) ~ 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" ~ Tubing tail/ WLEG Perforation Summary Size Spf Interval (TVD) 2" PJ 6 8195' -8225' 4252' - 4262' 2" PJ 4 8660' -8680' 4384' - 4391' 2" PJ 4 8720' -8740' 4402' - 4407' I 8765' I 7" Halliburton Float Collar PBTD I 8850' I 7" Halliburton float shoe MPE-13Bi 0 DATE REv. BY COMMENTS 4/06/02 MDO Sidetrack Completion Nabors 27E 4/24/02 MDO Add perfs w CTU - E-line 9/1/04 Lee Hulme Recomplete as dual - Nabors 4ES ~ Oriç" 3 Elev. = 59.0' (Doyon 14) Orig. Hgr Elev. = 30.55' (Doyon 14) Note: 7" casing is landed on emergency slips Lono Strino 2-3/8" HES X-Nipple (1.875" pkg. bore) I 2966' I Well was sidetracked 3/27/02. Window @ 2506' - 2522'. 7" casing was run through window to the surface. Old shoe depth 5193' 2-3/8" HES X-Nipple (1.875" pkg. bore) ~ 7" x 2-3/8" Baker 'GT' Ret. dual Pkr 1.945"ID. ~ 7" x 2-3/8" Baker 'FH' Ret. Pkr 2.41"ID. ~ 2-3/8" HES XN-Nipple (1.875" pkg. bore) ~ No-Go 1.791" 2-3/8" Baker 'E' Hydro Trip Sub w/6' muleshoe pup (bottom depth) I 8651' I (1.97" pkg. bore) Hydro Trip Sub ELMD I 8647' I 1.75" ball. MILNE POINT UNIT WELL No.: MPE-13Bi API : 50-029-22536-02 BP EXPLORATION (AK) ~ ~ BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPE-13 Common Well Name: MPE-13 Spud Date: 2/4/1995 Event Name: WORKOVER Start: 8/20/2004 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/2/2004 Rig Name: NABORS 4ES Rig Number: ! IcodelNPT Date From - To I Hours Task Phase Description of Operations - 8/20/2004 13:00 - 14:00 1.00 MOB P PRE PJSM. Scope down & layover derrick. 14:00 - 15:00 1.00 MOB P PRE PJSM. Prep rig components, shop & camp for rig move to MPE-13. 16:00 - 22:00 6.00 MOB P PRE Lay plywood. Move rig off MPF Pad, road failed just beyond plywooded section between MPF pad & MPL pad. (7) hrs stand by time credited to rig for lost time due to road. 22:00 - 00:00 2.00 MOB P PRE Continue moving rig & rig components from MPF pad to MPE pad. 8/21/2004 00:00 - 02:30 2.50 MOB P PRE Continue to move rig & rig components from MPF pad to MPE pad. 02:30 - 05:00 2.50 MOB P PRE PJSM. Assemble rig components on well. Raise & scope up derrick. Rig accepted @ 05:00 hrs, 08/21/2004. 05:00 - 08:30 3.50 KILL P DECOMP PJSM. Rig up lines to tiger tank, install secondary, (HCR), valve on inner annulus. Rig up lines to tree. Test lines to 3500 psi, OK. Pick up lubricator & pull BPV. Monitor well. SITP & SICP = 250 psi. OIA = 50 psi. 08:30 - 11 :30 3.00 KILL P DECOMP PJSM. Commence circulating 125 deg seawater down tubing @ 2 bpm I 700 psi, taking returns thru choke to tiger tank. No gas, diesel returns. Pick rate up to 3 bpm 11000 psi, 4 bpm I 1550 psi holding 200 psi back pressure on choke. Circulate tubng volume+, (60 bbls). See diesel returns till 50 bbls away, then 9.5 ppg brine coming back. Shut in & bullhead 15 bbls @ 2 bpm 11700 psi. Continue to circulate @ 4 bpm till seawater returns. Bleed IIA & shut in well. Monitotr pressures. 11:30-12:00 0.50 KILL P DECOMP Watch well, pressures stabalizing @ 280 psi on tubing & inner annulus. 12:00 - 18:00 6.00 KILL P DECOMP Call for kill weight fluid & circulate remainder of seawater. 18:00 - 21:00 3.00 KILL P DECOMP Wait on fluid. Fill pits w/1 0.3 ppg fluid. 21 :00 - 00:00 3.00 KILL P DECOMP Open well. SITP 240 psi, Annulus 250 psi. Begin circulating well w/1 0.3 ppg fluid, 2 BPM @ 900 psi. Increased rate to 3 BPM @ 1200 psi. Pumped 248 bbls & annulus went on vacuum. SD & monitor well. Pumped 248 Bbls & lost 125 Bbls. Well turned around & started to flow. SI & ann, pressure incresed to 160 psi. Possible that tbg is not cut completely (very high circ pressure) & well taking much fluid. RIU & reverse circulate. Start @ 3 BPM, 900 psi. Increased rate to 4 BPM, 1250 psi. Losses were 1 BPM. Decreased rate to 3.5 BPM, 670 psi. Losses were 2 bbls in 10 min. 8/22/2004 00:00 - 01 :00 1.00 KILL P DECOMP Cont to circulate & kill well. Pumped total of 285 bbls of 10.3 ppg fluid. SID. TP 0 psi, Annulus 0 psi. Open well, well U-tubed for 5 min then quit. Well dead. 01:00 - 01:30 0.50 WHSUR P DECOMP Set TWC. Blow down & NID lines to tree. 01 :30 - 02:30 1.00 WHSUR P DECOMP Bleed off hanger void. NID X-mas tree. 02:30 - 04:00 1.50 BOPSUF P DECOMP N/U BOPE. 04:00 - 08:00 4.00 BOPSUF P DECOMP Pressure test BOPE as per BP I AOGCC. Lp 350 psi. HP 4000 psi. BOP test witnessing waived by Chuck Scheve wI AOGCC. 08:00 - 09:00 1.00 BOPSUF P DECOMP PJSM. P/U lubricator, pull two way check, UD lubricator. Skinned finger while laying down lubricator..1 st Aid...sent to Medic for disinfectant & bandage. 09:00 - 10:00 1.00 PULL P DECOMP PJSM. BOLDs. Pull hanger to floor..35K to break free, 41 K up wt. 7 bbls to fill hole. Order out 200 bbls more of 10.2 ppg NaBr & water back surface volume to 10.2 ppg to cut loss rate. 10:00 - 16:30 6.50 PULL P DECOMP PJSM. POOH w/2 7/8" completion string. 4' section of pup Printed: 9/7/2004 8:36:29 AM ~ ~ BP EXPLORATION Page 2 of 5 Operations Summary Report ...... .. ... Legal Well Name: MPE-13 Common Well Name: MPE-13 Spud Date: 2/4/1995 Event Name: WORKOVER Start: 8/20/2004 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/2/2004 Rig Name: NABORS4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations n. -.... -_.- --.-.. ---...--.----.-- 8/22/2004 10:00 - 16:30 6.50 PULL P DECOMP below "X" Nipple retrieved, cut looked to be very good. 16:30 - 18:00 1.50 PULL P DECOMP Clear & clean rig floor. RId tbg equip. RlU tools to run 3 1/2" DP. Load & tally 9 - 4 3/4" DCs. 18:00 - 20:00 2.00 CLEAN P DECOMP M/U BHA #1 to mill packer as follows: Shoe, 2 Extensions, drive sub, 3 Junk Baskets, Bit Sub, Bumper jar, Oil Jar & 9 - 4 3/4" DCs. TL = 331.00'. 20:00 - 00:00 4.00 CLEAN P DECOMP P/U 31/2" DP 1x1 & RIH wI BHA #1. 8/23/2004 00:00 - 01 :30 1.50 CLEAN P DECOMP Con't to P/U 3 1/2" DP & RIH. Tag up @ 7765'. 01 :30 - 02:00 0.50 CLEAN P DECOMP P/U kelly & break circulation. P/U 233 jts DP, + 24' Pup, + 9' kelly & verify tag @ 7765' DPM. 02:00 - 06:00 4.00 CLEAN P DECOMP Mill packer from 7765'. P/U 92K, S/O 53K, Rot 66K. Pump 4 BPM @ 900 psi. 60 RPMs, Torq 4-6.5K. WOB 2-10K. Made approx 2' to 7767' @ 0600 hrs. No losses noted while milling. 06:00 - 18:00 12.00 CLEAN P DECOMP Continue milling on Baker S-3 perm packer, using various techniques. Appears to be spinning on internal packer rings. 18:00 - 21 :30 3.50 CLEAN P DECOMP Mill on packer wI different weights & circ rates. Milled from 7767 to 7769' Packer came free. Push until Kelly down. 21 :30 - 23:00 1.50 CLEAN P DECOMP Circulate bottoms up. 4 BPM @ 800 psi. Had small amount of gas to surface. Monitor well. 23:00 - 00:00 1.00 CLEAN P DECOMP P/U 3 1/2" DP & single in. Tagged up @ 8725'. Bottom of tail pipe @ 8755' DPM. 8/24/2004 00:00 - 02:30 2.50 CLEAN P DECOMP POOH wI packer mill & 3 1/2" DP. 02:30 - 03:30 1.00 CLEAN P DECOMP UD BHA #1. Inspect shoe & clean out junk baskets. Shoe had chunk missing, bottom was worn smoothe & body had gouges on outside. Top & bottom junk baskets were empty. Middle basket was full of cuttings. 03:30 - 04:00 0.50 CLEAN P DECOMP Clear & clean rig floor. 04:00 - 04:30 0.50 CLEAN P DECOMP M/U BHA #2 to fish packer. BHA as follows: Overshot, extension, Top Sub, Bumper sub, Oil Jar, 9 - 4 3/4" DCs. TL = 304.55'. 04:30 - 08:00 3.50 CLEAN P DECOMP RIH wI BHA #2 on 31/2" DP. 08:00 - 08:30 0.50 CLEAN P DECOMP PJSM. Make up head pin on 88 stands & (1) single...., overshot @ 8726'. 100K up wt, 49K down. Circulate down @ 3 bpm I 625 psi. See down wt decrease to 38K wI 23' in...., overshot @ 8749'. Pick up & note increase in up wt & drag. Work down once more to ensure good bite. 08:30 - 10:00 1.50 CLEAN P DECOMP PJSM. Circulate bottoms up, reciprocating pipe while circulating. 10:00 - 11 :30 1.50 CLEAN P DECOMP POOH w/3 1/2" DP. See overpull w/2 stands out to 175K. Stacking wt. Set jars off (2) times @ 200 K. Work junk past BHA. 11:30-15:00 3.50 CLEAN P DECOMP Continue out of hole wI fish. 15:00 - 16:00 1.00 CLEAN P DECOMP PJSM. Break out & UD overshot & fish. Recovered packer & tail pipe assembly..., total length = 47.76'. 16:00 - 17:00 1.00 CLEAN P DECOMP PJSM. Pick up clean out BHA. 17:00 - 18:30 1.50 CLEAN P DECOMP M/U BHA # 3. Bit & scraper assy. 18:30 - 20:30 2.00 CLEAN P DECOMP RIH wI BHA #3 on 31/2" DP to 8031'. 20:30 - 21 :00 0.50 CLEAN P DECOMP P/U storm packer, RIH & set @ 25'. Test to 1000 psi. 21 :00 - 22:30 1.50 BOPSUF P DECOMP NID BOPE. 22:30 - 00:00 1.50 WHSUB N MISC DECOMP Jack up rig to allow clearance for additional spool. 8/25/2004 00:00 - 06:00 6.00 WHSUB N MISC DECOMP Jack up rig. Need to raise rig 18" for spool & BOP clearance. Pad soft around jacks. Sills unstable. Call for larger matting boards to distribute weight better. Lay down excess DP. Printed: 9/7/2004 8:36:29 AM ~ ~ BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: MPE-13 Common Well Name: MPE-13 Spud Date: 2/4/1995 Event Name: WORKOVER Start: 8/20/2004 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/2/2004 Rig Name: NABORS 4ES Rig Number: I I Date From - To Hours Task Code NPT Phase Description of Operations -----------.--.-.-.--. -..-.--.-... .------- ._.._..n___- 8/25/2004 06:00 - 06:30 0.50 WHSUB N MISC DECOMP Evaluate situation. Opt to rig down & move rig off hole, then bring in matting boards to eventually raise level of rig. 06:30 - 08:00 1.50 WHSUB N MISC DECOMP PJSM. Set tbg hanger & N/U tree. 08:00 - 18:00 10.00 WHSUB N MISC DECOMP PJSM. Level up rig. Scope down & layover derrick. Remove shimming from under rig. Pull pits & pipe shed off. Pull rig sub off. Bring in mat boards & spot around well head. 18:00 - 00:00 6.00 WHSUB N MISC DECOMP Lay in matting boards & sills. Back rig sub up on matting platform. Center over well. Shim up rig. Set rig hydraulic pads. Prep to raise & scope derrick. 8/26/2004 00:00 - 00:30 0.50 WHSUB N MISC DECOMP Finish Shimming up rig. 00:30 - 01 :30 1.00 WHSUB N MISC DECOMP Raise & scope derrick. 01 :30 - 03:30 2.00 WHSUB N MISC DECOMP Mat & spot in Pipe Shed. 03:30 - 05:30 2.00 WHSUB N MISC DECOMP Mat & spot in Pits. 05:30 - 06:00 0.50 WHSUB N MISC DECOMP RlU lines to pits. 06:00 - 08:00 2.00 WHSUB P DECOMP N/D tree, pull hanger. N/U FMC Gen V 11" x 11" 5M tubing spool wI alignment pins & false pack off sleeve. Align spool as per J. Cubbon & L. Hulme.Test pack off & void @ SOOO psi, good test. 08:00 - 10:00 2.00 BOPSUF P DECOMP PJSM. N/U 135/8" x 5M BOPE. 10:00 - 10:30 0.50 BOPSUF P DECOMP PJSM. Test flange @ 250/4000 psi, 15 min, good test. 10:30 - 12:00 1.50 BOPSUF P DECOMP PJSM. RIH wi 31/2' DP to 25' (+ -). Release RTIS. Well on slight vacuum. POOH & UD Halliburton tools. 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM. RIH picking up DP. Light tag @ 8764' DPM. 115K up wt, 45K down. 13:30 - 15:00 1.50 CLEAN P DECOMP PJSM. Reverse circulate hole clean @ 5 bpm I 8S0 psi. Bottoms up showed no solids in returns, no indication of fill. 15:00 - 19:00 4.00 CLEAN P DECOMP PJSM. POOH & UD 3 1/2" DP. 19:00 - 20:00 1.00 CLEAN P DECOMP Cut & slip 84' of drilling line. 20:00 - 00:00 4.00 CLEAN P DECOMP Con't to POOH & UD 3 1/2" drill pipe. 8/27/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP UD BHA #3. 01 :00 - 02:00 1.00 CLEAN P DECOMP Clean out junk baskets. Clear & clean rig floor. 02:00 - 04:00 2.00 BOPSUF P RUNCMP Set test plug. Change out rams for 2 3/8' tubing. Test same; LP 250 psi, HP 4000 psi. 04:00 - 04:30 0.50 BOPSUF RUNCMP Bleed off. UD test plug. RD test equip. 04:30 - 05:00 0.50 RUNCor P RUNCMP RlU tubing tools to P/U & stand back 2 3/8" long string. 05:00 - 05:30 0.50 RUNCor p RUNCMP Hold PJSM & review tubing running procedure. 05:30 - 14:30 9.00 RUNCor P RUNCMP P/U 2 3/8" TC II tbg & RIH, torquing each connection to 1300 ft/lbs. 258 its total. 14:30 - 18:00 3.50 RUNCO' P RUNCMP POOH & stand back 86 stands of 2 3/8' long string, using thread protectors on pin end. 18:00 - 19:00 1.00 RUNCm p RUNCMP PJSM wI new crew. UD TIW valve. Prep to P/U short string. 19:00 - 00:00 5.00 RUNCm p RUNCMP P/U 2 3/8' short string & RIH. 8/28/2004 00:00 - 01 :30 1.50 RUNCm p RUNCMP Con't to P/U & RIH wi 258 its of 2 3/8' tbg. Short string. 01 :30 - 05:00 3.50 RUNCm p RUNCMP POOH & stand back 86 stands, 2 3/8' short string. 05:00 - 06:00 1.00 RUNCm p RUNCMP RID rig floor. 06:00 - 07:00 1.00 RUNCm p RUNCMP Service rig. Fiinish RID floor. 07:00 - 09:30 2.50 BOPSUF P RUNCMP Set test plug. Change out rams for dual 2 3/8' rams. test rams Lp 250 psi. HP 4000 psi. Change out kill unibolt seal ring. 09:30 - 10:00 0.50 BOPSUF P RUNCMP Pull & UD test plug. RID test equip. 10:00 - 12:00 2.00 RUNCm p RUNCMP RlU dual string handling tools. 12:00-12:30 0.50 RUNCm p RUNCMP Hold PJSM wi all hands. review running procedures. 12:30 - 15:00 2.50 RUNCm p RUNCMP M/U, RIH wi packer assys & space out packers wi 14 jts tbg. 15:00 - 18:00 3.00 RUNCm p RUNCMP PJSM. Rig up & RIH wi dual string completion, running stands Printed: 9/712004 8:36:29 AM ~ ~ BP EXPLORATION Page 4 of 5 Operations SUmmary. Report Legal Well Name: MPE-13 Common Well Name: MPE-13 Spud Date: 2/4/1995 Event Name: WORKOVER Start: 8/20/2004 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/2/2004 Rig Name: NABORS 4ES Rig Number: Date From - To Hours TasklCodel NPTI Phase Description of Operations ..-----.-.-.- !' 8/28/2004 15:00 - 18:00 3.00 RUNCor p RUNCMP out of derrick. Torquing 2 3/8" TC II connections to 1300 ftllbs, using Jet Lube Seal Guard. Inspecting & drifting pin ends on stands discovered pin end on stand #2 would not drift due to slight crimping. POOH to packer inspecting connections & laid down (3) its totaL., all in long string. 18:00 - 00:00 6.00 RUNCO' p RUNCMP PJSM. Continue to run dual string completion, drifting stands while RIH. 8/29/2004 00:00 - 00:30 0.50 RUNCm p RUNCMP Con't to RIH wI stands of 2 3/8" tbg. Took weight slightly on 33 stand. P/U & went in hole. Made connection & took weight 15' in on stand 34. (top pkr @ +1- 3100', bottom packer @ 3600' + -). 00:30 - 03:00 2.50 RUNCm tJ DPRB RUNCMP Stand back stand. R/U circ equip. Mix & pump 20 Bbl EP Mud-Lube pill. Spot around packers. RID circulating equip. P/U stands & RIH. Tag up @ same spot 15' in on stand 34. 03:00 - 06:00 3.00 RUNCm ~ DPRB RUNCMP POOH & stand back completion. 06:00 - 06:30 0.50 RUNCor DPRB RUNCMP Service & lube rig. 06:30 - 09:00 2.50 RUNCor DPRB RUNCMP Con't to POOH wI 2 3/8" completion. Stand back stands. 09:00 - 10:00 1.00 RUNCor ~ DPRB RUNCMP Change out elevators. POOH & UD 14 jts & packer assys. 10:00 - 10:30 0.50 RUNCor DPRB RUNCMP RID tbg equip. Clear floor. 10:30 - 12:30 2.00 BOPSUF N DPRB RUNCMP Drain BOP stack. Install & test test plug.. Change out dual rams to 2 7/8" x 5" variable rams. R/U test flange. 12:30 - 16:30 4.00 BOPSUF N DPRB DECOMP Test BOPE as per BP/AOGCC requirements. LP 250 psi. HP 4000 psi. BOP test witnessing waived by John Crisp wI AOGCC. 16:30 - 17:00 0.50 BOPSUF N DPRB DECOMP Pull Test plug. Install Wear Ring. 17:00 - 18:00 1.00 CLEAN N DPRB DECOMP R/U to P/U 3 1/2" DP. Strap BHA #4. 18:00 - 19:00 1.00 CLEAN N DPRB DECOMP P/U BHA #4. Laule Tool, PxP Sub, Boot Basket, Sea per, Bit Sub, Bumper Jars, Oil Jars, 9 - 4 3/4" DCs. TL = 318.60'. 19:00 - 00:00 5.00 CLEAN N DPRB DECOMP P/U 31/2" DP 1x1 & RIH wI BHA #4. Took weight @ 3710' (10K). P/U & work pipe, Pipe went thru. Con't to RIH. 8/30/2004 00:00 - 00:30 0.50 CLEAN N DPRB DECOMP Con't to P/U 3 1/2" DP 1x1 & RIH wI BHA #4. Tag up @ 8100'. P/U wI 20K overpull. 00:30 - 02:30 2.00 CLEAN N DPRB DECOMP P/U & work pipe. Con't in hole to 8310' Work pipe had to P/U kelly & rotate thru. RIH. Appear to pushing junk/debris ahead of shoe. Took weight @ 8560',8597' & 8637'. Work thru. Took weight @ 8685', had to P/U kelly & rotate thru. Set back kelly & work pipe, junk ahead. Con't in hole, push & tag up @ 8757'. 10' Above previous PBTD. Called good. 02:30 - 03:30 1.00 CLEAN N DPRB DECOMP POOH & UD 57 jts. 03:30 - 07:00 3.50 CLEAN N DPRB DECOMP POOH & stand back stands of 31/2" DP. 07:00 - 08:00 1.00 CLEAN N DPRB DECOMP PJSM. UD clean out BHA. Recovered (1) piece of rubber from the Laule Tool, appears to be of the annular preventor type. Also gouge on mill indicating encounter with hard junk. 08:00 - 09:00 1.00 EVAL P DECOMP PJSM. Pick up Halliburton RTTS. RIH on (9) 4 3/4" DCs. 09:00 - 14:30 5.50 EVAL P DECOMP RIH w/3 1/2" DP. 249 its total. 80K up wt, 55k down. 14:30 - 16:00 1.50 EVAL P DECOMP PJSM. Set RTTS @ 8175' DPM. Rig up First energy & test lines @ 4500 psi, OK. Close pipe rams & pressure IIA to 3500 psi wI rig pump, staging up, monitoring O/A. Finish pressuring up IIA wI First Energy to 4000 psi. Test f/30 minutes & chart, no bleed off. Max pressure on CIA during test = 600 psi wI no indication of communication between OIA & IIA. 16:00 - 18:00 2.00 EVAL P DECOMP PJSM. Release RTTS & POOH laying down DP. 18:00 - 21 :00 3.00 EVAL P DECOMP Con't to POOH & UD 3 1/2" DP. UD RTTS. Printed: 9/7/2004 8:36:29 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/30/2004 8/31/2004 9/112004 9/212004 ~ ~ BP EXPLORATION Operations Summary Report Start: 8/20/2004 Rig Release: 9/2/2004 Rig Number: Phase I I MPE-13 MPE-13 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES .-.-.-.---- I I From - To Hours Task Code NPT 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:30 02:30 - 03:30 03:30 - 00:00 00:00 - 01 :30 01 :30 - 04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 08:00 08:00 - 13:00 13:00 - 14:00 14:00 - 18:00 18:00 - 21:00 21 :00 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 06:00 05:00 - 06:00 0.50 BOPSUF P RUNCMP 0.50 BOPSUF P 2.00 BOPSUF P 1.00 BOPSUF P 0.50 RuNcmfP 1.00 RuNcmfP 1.00 RuNcmfP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 20.50 RuNcmfP RUNCMP 1.50 RuNcmfP RUNCMP 2.50 RUNcm P RUNCMP 1.00 RUNcm p 1.50 BOPSUF P 1.50 BOPSUF P 5.00 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP 1.00 WHSUR P RUNCMP 4.00 WHSUR P RUNCMP 3.00 WHSUR P RUNCMP 1.00 WHSUR P RUNCMP 2.00 WHSUR P RUNCMP 1.00 DHEQP P RUNCMP 1.00 WHSUR P RUNCMP 1.00 WHSUR P 3.00 WHSUR P RUNCMP RUNCMP 1.00 RIGD P RUNCMP Page 5 of 5 Spud Date: 2/4/1995 End: Description of Operations ---.n.- Drain BOP. Close blind rams. Cycle annular & check for looselshredded rubber. No loose rubber seen. A few chunks appeared to be out of annular. Clear rig floor. Pull wear ring. P/U, & set test plug. Change out rams for 2 3/8" dual string. P/U dual test plug. Test rams. LP 250 psi. HP 4000 psi. UD & RD test equip. Hold PJSM & review completion running order & procedures. M/U & RIH w/2 3/8" packers & tailpipe assy. R/U dual string handling tools. Start RIH wI dual string completion. Con't to RIH. Run dual strings 2 3/8" 4.6# L-80 TC II tubing, using Jet Lube Seal Guard pipe dope & torquing each connection to 1000 - 1100 ft Ilbs, drifting all connections after make up with 1.905" drift made up on 90' section of slickline. Pre Job held on all facets of the operation. Complete RIH wI dual 2-3/8", 4.6#, L-80, TCII tubing strings. Verify tallies, space out accordingly. Weights for both strings: P/U = 55K, SIO = 35K. P/U tubing hangers and M/U to strings. P/U landing joints and M/U to tubing hangers. Land Hangers and ensure accurate positioning of hangers in bowl. Pull and UD landing joints. P/U TWCs and set in tbg strings. Pump out BOP Stack. Change out 2 3/8" dual Pipe Rams. Install 2 7/8" x 5" single Pipe Rams. ND BOPE. NU Adaptor Flange and test at 5K. Good. NU CIW Dual String Tree. Test both String sides to 5K. Good. Pick-up Lubricator and pull TWCs from both Strings. Lay down same. Rig up Lines to Production Tree. Test Lines to 3,500 psi. Good. Rev circ 50 Bbls S/W @ 3 BPM, 5-600 psi. Rev circ 300 Bbls S/W wI corr inhibitor, 3 BPM, 5-600 psi. Rev circ 60 Bbls diesel freeze protect fluid. Drop 1-3/4" ball to begin Long String packer setting procedure per BOT rep. Bullhead after 1-1/2 hrs to get ball on seat. Set FH Pkr. Build pressure to 3,000 psi, hold and record for 30 mins. Good test. Increase pressure to 4,400 psi and shear HT Pressure sub. RIU to PT casing @ 2000 psi and record for 30 mins. Good test. RIU to short string and pressure up to 1500 psi to test isolation packer. Drop 3/4' ball and wait for 1 hr, then bullhead to seat. Set GT Pkr. PT SS to 3000 psi and record for 30 mins. Good test. Build pressure to 4100 psi to shear ball seat. Freeze protect short string w/15 Bbls diesel. Freeze protect long string w/15 Bbls diesel. P/U lubricator and install BPVs in both strings. Make up tree lift assy to top of tree. N/D tree above adaptor spool to facilitate rig move. Install temporary weather cap on tree equipped wI Otis connection and bleed valve. Scope and UD derrick. Printed: 9/7/2004 8:36:29 AM ) ) ~Øri q!ï(o.t Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration - Alaska Milne Point Unit / E-pad 09/01/04 Lee Hinkel ';:¡d)~TØW Packer Depth Pretest Initial 15 Min. 30 Min. weIlIMPE-13B I Type Inj. Is TVD I 4,242' TUbingl 01 01 01 01 Interval I P.T.D. 2020440 Type test P Test psi 1,500 Casing 0 2,000 2,000 2,000 P/F Notes: Pre-injection start MITIA. An AOGCC witnessed MITIA will be performed once the well is POI. I P weill I Type Inj. I I TVD I I Tub~ng I I I I I Interval I P.T.D. Type test Test psi Casing P/F Notes: weill I Type Inj. I I TVD I I TUb~ng I I I I I Interval I P.T.D. Type test Test psi Casing P/F Notes: weill I Type Inj'l I TVD I I Tub~ng I I I I I Interval I P.T.D. Type test Test psi Casing P/F Notes: weill I Type Inj'l I TVD I I TUb~ngl I I I I Interval I P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 2004-0901_MIT _MPU_E-13B.xls STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION - RECE\VED REPORT OF SUNDRY WELL OPERATIONS ~_... - f} ..,MA 1 . Operations Performed: ~~r ...~- AbandonD Repair Well 0 PluQ PerforationsD Stimulate D Oth~r~ Gas Cons. Comm4ssio ~ Alter CasingD Pull TubingO Perforate New Pool D WaiverD Tim~~» ~nchoraQe Change Approved Program 0 Operation Shutdown 0 Perforate IK] Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D Servicel!l 50-029-22536-02-00 7. KB Elevation (ft): 9. Well Name and Number: 59.00 MPE-13B 8. Property Designation: 10. Field/Pool(s): ADL-o47437 Kuparuk River Field / Schrader Bluff Oil Pool, Milne Point Unit 11. Present Well Condition Summary: Total Depth measured 8852 feet true vertical 4438.3 feet Plugs (measured) None Effective Depth measured 8765 feet Junk (measured) None true vertical 4414.6 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 34 - 114 34.0 - 114.0 1490 470 Intermediate 2474 9-5/8" 36# L-80 32 - 2506 32.0 - 2441.6 5120 2370 Production 8819 7" 26# L-80 31 - 8850 31.0 - 4437.8 7240 5410 Surface 2473 13-3/8" 68# L-80 33 - 2506 33.0 - 2441.6 4930 2270 Perforation depth: Measured depth: 8195 - 8225, 8660 - 8680,8720 - 8740 True vertical depth: 4252.94 - 4262.56, 4385.87 - 4391.35,4402.3 - 4407.75 Tubing ( size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 28 - 7821 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 7781 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: 0 0 -607 0 1118 Subsequent to operation: 0 0 -456 0 1067 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentD ServiceŒ] Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations - ! OilD GasD WAGD GINJD WINJŒ WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature ~ - A. r- CI~ Phone 564-4657 Date 8/31/04 '" \J ORIG\NAL IIØI8 Bf L SEP 0 3 2004 Form 10-404 Revised 4/2004 MPE-13B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/17/04 Perforate 8195'-8225' 6 SPF BBLS 0 FLUIDS PUMPED : TOT Al No Fluids Page 1 TREE: 29/16"-5M FMC WELLHEAD: Gen 511" 5f1 2-7/8" L-80 eue T&B, 2.5" CIW typed 'H' profile 133/8", 68#/ft, L-80 Butt ~ 95/8", N-95/L-80, NSCC Shoe KOP @ 1200' 70+ @ 3,300' - PBTD Max. Angle 77 deg. @ 4340' 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift ID = 2.347", cap. = 0.00592 bpf) 7" 26 ppt, L-80, NSCC production casing (drift 10 = 6.151", cap. = 0.0383 bpf) Perforation SummaI)' Ref Lo" . SWS SCMT 4/24/02 Size SPF Interval ClVm 2"PJ 6 8,195' - 8,225' 4,252'- 4,262' 2"PJ 4 8,660' - 8,680' 4,384'-4,391' 2"PJ 4 8,720' - 8,740' 4,402'-4,407' "'_""~r-tl~~ "'~~~-ry ""_.. ,~..., 07/" 4/0" <3~<=<=L Slz- SPF TVI:> 4.S' 4.S' ""~rlz~nt_' vv_"'>~._, ""~U_d '.n_. (3/"'"" ~'d_)" '2.S7S' t~"'.32" MPE-13Bi DAlE 4/06/02 REV. BY COMMENTS MDO Sidetraek Completion Nabors 27e 4/24/02 MDO Add perfs w/ CTU - E-Line ORIG. KB. ELEV = 53.8' (N27E) ORIG. KB - BF = 28.7' (N27E) GROUND LEVEL = 24.7' 2-7/8" HES X-Nipple( 2.313" id) I 2,270' I Well was side tracked 3/27/02 window 2506' - 2522' and 7" casing was run through window to surface. Old shoe depth 5193' 2-7/8" HES X-Nipple( 2.313" id ) I 7,756' I 7" x 4.5" Baker S-3 Packer I 7,780' I I 7,808' I 2-7/8" HES XN-Nipple( 2.205" id ) WLEG ELMD 7" float collar (PBTD) I 8,765' I 7" float shoe I 8,850' I ~~;:'~. 'if5":£"!'-;"~';;kc;:. R..tr;"~'T~:--SS2' I Hc>~cc> 9-S/8" clap T~p ~. TlVV ""~"z~nt_' p_ck_. I, 2 "7S' I 9 5/S"". "'-95/L-SO. ...see s"'~- I '2.S3'" I .. '/2"" ""~"z~n'_1 S_ctl~n P_ck C>ff S~b .. "2"". '2..........Se,- L-SO 'S.32S' , S.34S' MILNE POINT UNIT WELL E-13Bi API NO' 50-029-23079 BP EXPLORATION (AK) ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRQVAL \ "" '". II".; i! '" .-,~, '1..1,'.' , I 20 MC 25.280 ?D04 ÁI ()~ /4 ~ ~ ~ ~ 1. Type of Request: [J Abandon 0 Repair Well [J Plug Perforations [J Stimulate [J Alter Casing II Pull Tubing 0 Perforate New Pool [J Waiver [J Change Approved Program 0 Operation Shutdown 0 Perforate [J Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: ' P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 59.0' 8. Property Designation: ADL 047437 Total Depth MD (ft): 8852 Casing.", Structural Conductor Surface Intermediate Production Liner Convert to Dual Injector II Other 0 Time Extension 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic Ii Service 5. Permit To Drill Number 202-044 6. API Number: 50- 029-22536-02-00 9. Well Name and Number: MPE-13Bi 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff Total Depth TVD (ft): Effective Depth MD (ft): 4438 ,,8765 LengthSizè , 12. Attachments: Ii Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 15, 2004 0 Oil 0 Gas 16. Verbal Approval: Date: rGJ'?1v')' -->- \"< 0 GINJ Commission Representative: J.:J]:-' \.........- 17. I hereby certif that the foregoing is true and correct to the best of my knowledge. Printed Na David Reem Title Drilling Engineer ~ ()- ~ 80' 2475' 2476' 8819' 20" 13-3/8" 9-518" 7" Perforation Depth MD (ft): Perforation Depth TVD (ft): 8195' - 8740' 4253' - 4408' Packers and SSSV Type: 7" x 4-1/2" Baker S-3 Packer Signature Depth TVD (ft): Plugs (measured): 4415 N/A , 'nfQ:"BIJrst" Junk (measured): NIA ,,'Cóllåpse' 112' 2506' 2506' 8850' 112' 2445' 2445' 4438' 1490 5020 6870 7240 470 2270 4760 5410 Tubing Size: 2-7/8",6.5# Tubing MD (ft): 7821' Tubing Grade: L-80 Packers and SSSV MD (ft): 7780' 13. Well Class after proposed work: 0 Exploratory 0 Development Ii Service 0 Plugged ~INJ 0 Abandoned 0 WDSPL Contact David Reem, 564-5743 Phone Commission Use Only Date ~/IS' /01 Prepared By Name/Number: Sondra Stewman, 564-4750 I Sundry Number: 304-,) 7 c¡ Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity 0 BOP Test ~echanicallntegrity Test 0 Location Clearance ~ ~ '\ t:. \L. CJ ~ L- 'i Mù\'-s.'\",- O<:C.D~~l ~\o\aß. ..-9fl Other: 'J:-~~c::\tc '''-C '- '''' 2, \ -- COMMISSIONER APPROVED BY THE COMMISSION ~~i/ Date ~ '/J ) S mit I Dup icate ORIGINAL ) ) Project: MPE-13B Conversion from Single String OA Injector to Dual NB/OA Injector MPE-13B Status: POI, NB Perforations 8195 - 8225' MD (4253' - 4263' TVDkb) added 6/17/2004 Scope of Work: Follow all MPU/BP safety procedures - No accidents, spills, or harm to the environment! SWS E-Line A) Chern cut tubing in between Bakers 8-3 Packer and X-Nipple Nabors 4ES 1) MIRU Nabors 4ES 2) Kill Well 3) Pull 2 7/8" tubing above chern cut 4) Mill and retrieve Baker S-3 Packer at 7780' MD 5) Bit & scraper run /FCO to PBTD 6) Change out wellhead and tubing hanger 7) Run 2 3/8" dual completion and set packers 8) Install new tree Note: Flanges to be installed in each injection leg to allow for future gas injection 9) RDMO Nabors 4ES Pressure: 6/12/2004 1693 psi @ 4000' TVDss = 0.423 psi/ft (8.14 ppg) v ~ Ga.'? ~\"'~ '<::C- ~ a" ~?~~"-~\'- 0.0\\-0-, ~C..J \'" 'Jc.."\O.~<è \'~\~.ç\. 'S~Cè ~\O \0 ß ~~\~ \ - i?ú.,~~- (""d-) (o.-~). J/t-0fv1 TREE: 29/16" - 5M FI\....,) WELLHEAD: Gen 5 11" 51\ 2-7/8" L-80 eue T&B, 2.5" CIW type 'H' profile 133/8", 68#/ft, L-80 Butt ~ 95/8", N-95/L-80, NSCC Shoe ~ KOP @ 1200' 70+ @ 3,300' - PBTD Max. Angle 77 deg. @ 4340' 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift 10 = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, NSCC production casing ( drift 10 = 6.151", cap. = 0.0383 bpf) Perforation Summary Ref. Log: SWS SCMT 4/24/02 Size SPF Interval (TVD) 2"PJ 4 8,660' - 8,680' 4,384'-4,391' 2"PJ 4 8,720' ~ 8,740' 4,402'-4,407' MPE-13Bi ~ ) O"IG. KB. ELEV = 53.8' (N27E) ORIG KB - BF = 28.7' (N27E) GROUND LEVEL = 24.7' 2-7/8" HES X-Nipple( 2.313" id) I 2,270' I Well was side tracked 3/27/02 window 2506' - 2522' and 7" casing was run through window to surface. Old shoe depth 5193' 2-7/8" HES X-Nipple( 2.313" id ) I 7,756' I 7" x 4.5" Baker S-3 Packer I 7,780' I 2-7/8" HES XN-Nipple( 2.205" id ) I 7,808' I WLEG ELMD 7,820' 7,810' ~ 7" float collar (PBTD) I 8,765' I 7" float shoe I 8,850' I P.."r"c:.ratloOoW'"'ll S.............r..-.o1!IIIry R_-r Ie>g: 07/~4/0~ C::;:;R/C::C::L Slz«!Þ s.F"~ 'r'~;-:~=r:~~.~ ~,-"ru-I (.'-'D) § [;l . ::;U~:: ~ g~~g::g~~~: ~~g~~::~g~~:~ ~ ~~~~~.~š~.~;;,~o~<;;: R"trICovaoIb'r8.552' I K IrS"1lI""..1< "ROO ~;;:'"'Ir""torl R R 4.5" 5 8260-8:;;>70' (7087'-7095') t:I t:I 4505 PovverJot Charge.s - 72 dC!tgroe. , Hovvco 9.-5/8.. clap F>ha...lng I I ~ ~ loOp.or IIV"\/' t-'orl;;e.ontcal pQokof'" 12.~7"a' ~ \. \. \. } $) 5/e". N-95/L-BO. ,""SC::C:: Shoo<> I 12.03:=>' I t t t B 1/2" Horl-",or>'m' S...otlor> t t . . l Puok c>rr Sub I 16.326- ~1~tl~OdnN':,lø~t;I;t::~!:O~lcjC» r/ 12.B76' 10"16.326 --.--..-." 4 1/2", 12.6#,NSC. L-BO I "16.34B' DATE 4 / 06 / 02 4 / 24 / 02 REV. BY MOO MOO COMMENTS Sidetrack Completion Nabors 27e Add perfs w/ CTU - E-Line Mil NF POINT UNIT WFI I F-13Bi .API NO: 50-0'9-'3079 BP EXPLORATION (AK) 01"'\11 KB. ELEV = 53.8' (N27E) ORIG KB - BF = 28.7' (N27E) GROUND LEVEL = 24.7' ~CIW 21/16"5M. "J¡ String MPE.13Bi Proposed Wellhead: 11" x 2 3/8" 5M FMCDual String Tbg. Hng: 23/8" 1ST top and bottom 2" CIW-H SPV profile: 133/8", 68#/ft, L-80 Butt ~ 95/8", N-95/L-80, NSCC Shoe ~ KOP @ 1200' 70+ @ 3,300' - PBTD Max. Angle 77 deg. @ 4340' 2-3/8" 4. 7#/ft., L-80, 8 rd. TCII tbg. (Drift 10 = 1.901 ", cap. = 0.00387 bpf) 7" 26 ppf, L-80, NSCC production æsing ( drift 10 = 6.151 ", æp, = 0.0383 bpf) Note: Well was side tracked 3/27/02 window 2506' ~ 2522' and 7" casing was run through window to surface. Old shoe depth 5193' Perforation Summary Ref. Log: SWS SCMT 4/24/02 Size SPF Interval (TVD) NB Sands 2" PJ 6 8195' - 8225' 4253'-4263' OA Sands 2"PJ 4 8,660' - 8,680' 4,384'-4,391' 2"PJ 4 8,720' - 8,740' 4,402'-4,407' 7" float collar (PBTD) I 8,765' I 7" float shoe I 8,850' I ------------ EI bI j Short String 2-3/8" HES X-Nipple (1.875" pkg. bore) I -3000' I Long String 2-3/8" HES X-Nipple (1.875" pkg. bore) [ -3000' I Short String 2-3/8" HES X-Nipple (1.875" pkg. bore) [ 8098' I Long Strin9 2-3/8" HES X-Nipple (1.875" pkg. bore) I 8188' I I 8140' I 7" x 2-3/8" Baker "GT" Ret. dual pkr. 1.945" ID. . 2-3/8" HES XN-Nipple (1.875" pkg. bore) I 8184' I No-Go 1.791" I 8186 I Tubing tail I WLEG Tubing tail I WLEG 18624 I I I 7" x 2-318" Baker pkr. 1.945" 10. 2-3/8" HES XN-Nipple (1.875" pkg. bore) I 8648 No-Go 1.791" I 8650 EI bI ------------. p..,r'l'CÞratICJon SII...I.......IT1I.a...-y RI_1' .e>g: 07'''''4'0'''' c::;:,A'C::::C::::L Size SPF I nteo rv'a I (TVD) =I J:::I K 'p~'-I .k' ..c-.:.' ~. "tol'"""lrl :j ~ - 1:~:: ~ g§g¡g::g~~~: ~~g~~::~g~~:~ ~ ~~;:v~~. ;'5~'~~~C>~~ R""~r''''V'''bra.5S2' I 10< .p.-r.rIIK "F=\" ~""'l"""Irl R R 4.5" <3 8260-8270' (7087'-70ÇJ5') t:I t:I 4505 PO'VV0rJG't Ch.o.rges - 7"2 c:legroe, ¡. t-tovvco 9-5/8.' C::IEU=~ F>h..."'lng I I ~ ~- Top of TIVV l-to~l...c::.onlal pmokor'" '12.57'8' ~ \ \ \ ~ ~ D 5/0", N-9S/L-OO. NSC::C:: Shoo I 12.035' I l \ \ 0 1/2" He>r.£on la' Soclle>n l l . . \ F"mc.k <:>rr Sub I '16.320- ~1~t'fo~nlll~lo~<~I~~~!:<O~ldC!Jr) r/ 12.87'6" to'16.326'- .-.------Þ 41/2". 12.6"..c..,.....,SC:. L-BO I '16.348' DATE 4 I 06 I 02 4 I 24 I 02 REV. BY MOO MOO COMMENTS Sidetrack Completion Nabors 27e Add perfs wI CTU ~ E~Line Mil NF POINT UNIT WFI I F.13Bi API NO: 50.0'~.'3079 BP EXPLORATION (AK) ) ) MECHANICAL INTEGRITY REPORT' .... . . . . ' . . '. &Od- -0 iþ4- S./~Q'- 6~ OPER & FIELD ~ \' \J\\\",~ \'O\^'-\- M?F-\sß\ ::PUD DA!E: : ?.IG R.sLE;.S~: . WELL NUMBER TD: <¿f65~ ,MD.. 4'-\3d:rvÐ; :?BTD: ~ ~')~y HI? ~ . Shoe: )S)ss"O MD TVD i DV:' ~~ MD :':";:je:!:' : N~ Shoe: MD ~ -. '""'"\ 3/. <1>\40 - '-1 D!.!: g : Q"i (f I ~p acke:!:" ~ ';),-\ HI) ~ole Size 'bl/;r.. a.nå N ~ TVD ~!;LL DATA Ca.sing: ¡ ,I j !, ~ ¡ Î ~ it! I~t -1'lD 1.m <=6' \ <ø (0 TVD i Set ê. t ~(oÇO Perfs ~C-~t;;C) to 'ís'"1;)o~:~Ò:J. . ~~~-4~c;. \ . 4~():) -c-\'1l)1 '~cl TVD i 70P: :VI) t:ECH.AN!C;'~ INTEGRITY - PART /1 30 min Annulus Press Test: 'îP 15 min COûJ!!lents: ~ . ~\\ ~ 'Ð~""o~ t):¡~'è.~~~\Q6~ <;'\"-~(ê <;'--\Ñ"-\ w ~Q\ HECHÞ-1\[ICÞ-L INTEGRITY - PART 12 p~'-J'\D~c::>\'l pö~~Q.~~ \.~ Cement: Volumes :'. Amt.. Liner ~.Þ\ ; Csg "SSÇ" i DV ~ ~ . -:41 ~ , e :: ,¡J 0- !~ t :' t. ø ~ 1j ~ j h " <! ~ Proåuc.tion Log: Typ~ ~ -.. l, I~ 1. . l' 0 CONCLUSIONS: ; LW 0 : ~ ';) ? art: 1 : . ?an: #2: lNo.~\->s\\\ ~<lK"~\.~ ~ 'S~, "\ ~\(h~",~" \'~\()\:1ès,. , ' .,?~~~W)\~ ~~cJO~ ~ \ð~~<è.'\r"\ ~ß e" \.\?t~"ðO~\o\~1,ðtf\ . \-l\ r '\ So . '\ \~ \'-{ It-- '2'C~0, hQ~ 7 //(. -o~ ..... .? t ¡ . . C¡¡¡t -"01 to cover/er£s ~ \'D()<::'~ t\QCfLS'SO.'l .~ <.O~, ~ vr'~ ,,\-.:.s 5tO . . . Theoretical TOe \l'Jl ~<o ~ s \a~<tS\\\M..(~~~ '0 ~ <o'-lOO t <:>c.. k'\ \.\ I ()$ - ()::> Cement Bond Log (Yes or No) \{~ ; ;Ln AOGCC File .~~~ CBL E:va1uation. ::;one above perfs <':"'<è..~"\- ,\-\JQ..\'"'--I~~"-. \x:\o-..J '6\-tt'iJ'~ ~\~..-s\;l,\~~ . þ.,~~\\lli~ ~ ~\-\\A C~\':9ò~\-m"-C-I.~0Z ¡Evaluation . ' ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Æ{,~ CD l?7, C/;/~Z 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: Suspend D Repair Well D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate[¡ WaiverD Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0440 BP Exploration (Alaska), Inc. Development D Exploratory D Stratigraphic 0 Service ŒJ 9. Well Name and Number: MPE-13B 10. Field/Pool(s): Kuparuk River Field / Schrader Bluff Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 4438.3 8765 4355.6 Size MD TVD 6. API Number 50-029-22536-02-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 59.00 KB 8. Property Designation: ADL-047437 11. Total Depth MD (ft): 8852 Casing Length Plugs (md): Junk (md): None None Burst Collapse Conductor Intermediate Production Surface Perforation Depth MD (ft): 8660 - 8680 8720 - 8740 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 80 2474 8819 2473 20" 91.5# H-40 9-5/8" 36# L-80 7" 26# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 4385.87 4391.4 4402.3 4407.8 top bottom top bottom 34 114 34.0 114.0 1490 470 32 2506 32.0 2441.6 5120 2370 31 8850 31.0 4437.8 7240 5410 33 2506 33.0 2441.6 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 2.875 " 6.5 # L-80 28 7821 Detailed Operations Program ŒJ BOP Sketch D fì June,~OO4 7781 RI2(,'EIV€11 13. Well Class after proposed work: , I , tl UN 7 co ~~~~.Ar1tn 0",' P(JllA ExploratoryD Developme ~ Gas ~iceLKI ì IJ:nc¡. ~. ('.om 15. Well Status after proposed work: '~ge 'f!J~n Oil D GasD PluggedD AbandonedO WAG D GINJD WINJŒ) WDSPLD Prepared by Garry Catron 564-4657. Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal D 14. Estimated Date for Commencinç¡ Operation: 16. Verbal Approval: "'fé<S Date: 6; j /(.')(-( Commission Representative: "f$')""'I-)S !'Ja;'X)Ñr.cQ. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean Petersen Printed Name Signature Sean Petersen So.- O~~ Title Phone Petroleum Engineer 564-5025 6/10/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry N3Qe[/ .2 30 Other: BOP TestO Mechanciallntegrity Test D Location Clearance D "- BY ORDER OF Ch ? ./ /l£ THE COMMISSION Date: , t..¡ "T JUN 2 2 ilüüt~ ~BfL Form 10-403 Revised 12/2003 ORIGINAl SUBMIT IN DUPLICATE TREE: 29/16" - 5M FIVI$ WELLHEAD: Gen 5 11" 5~ 2-7/8" L-80 eue T&B, 2.5" CIW type 'H' profile 13 3/8", 68#/ft, L-80 Butt ~ 95/8", N-95/L-80, NSCC Shoe ~ KOP @ 1200' 70+ @ 3,300' - PBTD Max. Angle 77 deg. @ 4340' 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift 10 = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, NSCC production casing ( drift 10 = 6.151", cap. = 0.0383 bpf) Perforation Summary Ref. Log: SWS SCMT 4/24/02 Size SPF Interval (TVD) 2"PJ 4 8,660' - 8,680' 4,384'-4,391' 2"PJ 4 8,720' - 8,740' 4,402'-4,407' MPE.13Bi ~- "",,'»O§~.~~iJ~1('r ) ORIG. KB. ELEV = 53.8' (N27E) ORIG. KB - BF = 28.7' (N27E) GROUND LEVEL = 24.7' 2-7/8" HES X-Nipple( 2.313" id) I 2,270' I Well was side tracked 3/27/02 window 2506' - 2522' and 7" casing was run through window to surface. Old shoe depth 5193' 2-7/8" HES X-Nipple( 2.313" id ) I 7,756' I 7" x 4.5" Baker 8-3 Packer I 7,780' I 2-7/8" HES XN-Nipple( 2.205" id ) I 7,808' I WLEG ELMO 7,820' 7,810' ~ 7" float collar (PBTO) I 8,765' I 7" float shoe I 8,850' I P....-rc::.r'.atICÞr"'II SL.8.......-.......,..;ary ~....... ICÞg: 0'7/"14/0"'1 C;FI:/C::C:::L Size SPF IntervDlI ("".'-'0) J::I J::I . ~'I-IC'1I......k"IC-:"~Øllr"IId 1::::1 1::::1 :::t:g: g ~~~g::~~~~: ~~8gi:§::~8~~L. ~ ~~~~~. ~t5S¿'~~;:;~k~ Re1:rieVi~~552' I 1<\0 'r...r. ,k "0=0." =.......d R A 4.5" 5 8260-8270' (7087'-7099:J t:1 4505 Povver..Je1: Charges - 72 degre.-. ... u.'... ..",... .....,. .~ Hovvco 9-5/8" CISP Phasing I ~ :::E:...... Top .or TIVV HOr"I..c.ont.ol po_ok..,. .. 2.S7'S" I ~ \ \ \ ~ '" 5/a". N-O<5/L-aO. NSCC ShC3- I 12.a305' I l l l a 1/2" HC3rlocC3n ,.... S_otlC3n l l l P&..ok C>fr Sub I ;e.32ðw HOr"'I.:.c:ontol VVe»lIbc:U'''.: ---------.. 41/2". '12.6#.NSCT L-BO I "'I6.34S' Slattod line.,. (3/"'1 au ""Ic:let) rl 12.876" ta1 6.326' DATE 4 I 06 I 02 4 I 24 I 02 REV. BY MOO MOO COMMENTS Sidetrack Completion Nabors 27e Add perfs wi CTU - E-Line Mil NF POINT UNIT WFI I F.13Ri API NO: 5n.O?Q.?~079 BP EXPLORATION (AK) ) ) bp ~I;.,~.,,~ ~~~~~ :.'l '~~~:. ....'.,;¡, ..:¥' '-'" . 'I).. S:... ,.w)Íit. ~.h)'_~ BP Exploration Alaska Milne Point To: Jerry Bixby and Clint Spence MPU Well Operations Supervisors Date: 06/10/2004 From: Sean Petersen Schrader Bluff Production Engineer COST: AFE: $30,000 MSD337395 Subject: MPE-13Bi Add Perforations OBJECTIVES: 1. Add NB perforations in MPE-13B support MPE-20A Category Step Description S 1 Tag TD with dummy gun E 2 Perforate NB sands: 8195' MD to 8225' MD (4253' TVDkb to 4263' TVDkb) * See below for detailed program * HISTORY & DISCUSSION: In April 2002, MPE-13A was sidetracked from a Kuparuk B & C sand producer to a Schrader Bluff OA sand injector to support MPC-41. With the recent addition of MPE-20A as an NB & OA sand producer in the southern part of the same fault block, NB perforations need to be added to MPE-13Bi to fully support MPE-20A. This is a temporary measure to provide injection support until MPE-13Bi can be worked over to a dual injector in the NB/OA sands. ,DETAILED PROGRAM: Category Step Description S 1 Tag TD with dummy gun to verify ability to run guns through 2 7/8" XN Nipple (2.205" I.D) at 7808' MD Perforate NB sands: 8205' MD to 8225' MD (4256' TVDkb to 4263' TVDkb) Perf gun: 2" HSD PowerJet 2006, HMX, 6.5g charge, 600 phasing, 6 spf Reference log: SWS SCMT 4/24/2002 Perforate NB sands: 8195' MD to 8205' MD (4253' TVDkb to 4256' TVDkb) Perf gun: 2" HSD PowerJet 2006, HMX, 6.5g charge, 600 phasing, 6 spf Reference log: SWS SCMT 4/24/2002 E E ) ) 2 3 )~OINTS OF CONTACT: Production Engineer: Sean Petersen Office: 564-5025 Home: 349-3098 MPU Wells Operation Supervisor: Jerry Bixby & Clint Spence Office: 659-6333 Fax: 659-6390 DISTRIBUTION: MPE-13B Anchorage Well File MPU Adn1Ìn. Assistant North Slope MPE-13B Well File MPU Ops Supervisors MPU Ops Coord Re: MPE-13B Add Perfs ) ) Subject: Re: MPE-13B Add Perfs From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 11 Jun 2004 14:01 :56 -0800 To: "Petersen, Sean D" <PetersSD@BP.com> Sean, Thanks for your reply. What you are proposing sounds reasonable. You will be perforating in another sand in the approved injection zone. Since this in an injection well, I believe the "workover" conservation order says that you should submit a sundry for such an operation. Since this is in the approved injection zone, I can verbally authorize the operation. You have verbal approval to proceed. Please send in the sundry next week. Tom Maunder, PE AOGCC Petersen, Sean D wrote: TOln, Thatù(S for the fast response! I was not platlning on shooting a lower shot density for a few reasons. First, there will be a .,,200 psi pressure difference between the two sands since the OA is being produced fron1 MPC-41 already, and the NB production just started with MPE-20A this week. That differential should help the OA sands take their share of the injection. Second, these are sn1all guns in large casing, and based on Schlumberger's SPAN progralu only those perforations on the low side of the hole will have significant forrnation penetration (""15.5" vs --.4.5"). Third, in talking to Monte Townsend, shooting a lower density would not buy us anything because our injection rates will not be high enough to cause any back pressure. (assuming 1000 bwpd is -0.69 bpm and rule ofthmnb is 1.0 bpIn per perforation to create back pressure). Upon further conversation with Monte T ownsend,we're going to propose shooting another 10' now so we do not have to perforate during the RWO. I'he new proposed perforation interval is 81.95 - 8225 MD (4253 - 4263' TVDkb). Ifwe are unable to inject at the desired rates prior to the RWO, vvc will look at re-perforating both sands with larger guns once the current cOlnpletion is out of the hole. The RWO should take place in the next few n10nths, and we'll be sending you the appropriate forn18 for that procedure ShOlily. Please let me knovv if you need anymore information. Sean -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, June 10, 2004 4:23 PM To: Petersen, Sean D Subject: Re: MPE-13B Add Perfs lof2 6/16/2004 4: 15 PM Re: MPE-13B Add Perfs ) ') Hi Sean, Are you going to perf at a lower shot density to control injection for the time being until the workover?? Tom Petersen, Sean D wrote: Tom, Apologies for the short notice, but I am planning on submitting a program to add NB perforations in MPE-13Bi to support the new production well MPE-20A. Milne Point has a number of e-line jobs that are tentatively scheduled to be completed within the next week, and I would like to get your approval to add this one to the list. We will be sending over the appropriate paperwork, but here is a copy of the proposed program for you to reVIew. «040610 MPE-13Bi Add Perforations.ZIP» FYI - we are also planning on converting MPE-13B to a dual injector within the next few months for better injection control between the sands. If you need anything else please let me know. Sean D. Petersen ACT Petroleum Engineer 907-564-5025 20f2 6/16/20044:15 PM ¡) ~- (y1(~ À (j \j Y I DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Permit to Drill 2020440 Well Name/No. MILNE PT UNIT SB E-13B Operator BP EXPLORATION (ALASKA) INC MD 8852- TVD 4432 -- Completion Date 4/25/2002 -- Completion Status 1WINJ REQUIRED INFORMATION Mud Log No - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Fnnt Number Name LIS Verification Cement Evaluation Log/ Data }~ "j-'Rpt ~- , g ~c ......A1406 ~D ~D C \.-.¡'õ945 asVörif¡Ç9tt~ÔtœW ~ 4.0014 'SeeNotes Well Cores/Samples Infonnation: Name ADDITIONAL INFORMATION y~ Well Cored? Chips Received? Y / N --- Analysis Received? '--'(J r-J Comments: Compliance Reviewed By: ~ Interval Start Stop Samples No Current Status 1WINJ Sf vt¿ ~ <J M~~~ API No. 50-029-22536-02-00 ~~~- Directional Survey ~ ~ (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH/ Scale Media No Start Stop CH Received 1 2506 8815 Open 7/2/2002 5 Col 7650 8750 Case 6/4/2002 2506 8852 Case 12/6/2002 Sent Received Daily,History Received? Formation Tops -" Comments Digital Well Logging Data / ¡ Rate of Penetration, Dual I Gamma Ray, Electormagnetic Wave Resistivity 2506 8815 Open 7/2/2002 7620 8718 Case 6/4/2002 SCMT Main Pass Sample Set Number Comments ~ >"'-- Date: JÀ u¡ (t~ M \v( ) aoa-oLJtp J / t-/00 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 30, 2002 RE: MWD FOffi1ation Evaluation Logs: MPE-13B, AK-MW-22054 MPE-13B: Digital Log Images: 50-029-22536-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND .RETURNING TH.E ATTACHED COPIES OF mE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ::dJ Signed:C/~'/Á ~ RECE\VEO DEC 06 2.002 0.. Ii. ,-."""" COt"(' Com1tlTIission Aiask6 ¡ \"¡ (¡. ,",0;) t ...;. I Anchoœge ) ) aœ-OLJy '] () 9ý S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 20, 2002 RE: MWD Formation Evaluation Logs MPE-13B, AK-MW-22054 1 LIS formatted Disc with verification listing. API#: 50-029-22536-02 PLEASE ACKNOWLEDGERECE,IPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Si~{&eoFJ RECEIVED 1/ I r-. f"! v; , I , .. /!1Il2 v~ L..... LV", AlaakaOiI & Gas Cons. Comm' . Anchorage lSSton ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylor Co" Chairman DATE: June 17, 2002 h\.. " SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~O " tV I BPX P.I. Supervisor ¡ð).- MPU E & J Pads ~(ý't>~ E-13B, J-20A FROM: Chuck Scheve MPU Petroleum Inspector Milne Point NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well E-13B Type Inj. S TV.D. 4134 Tubing 1900 1900 1900 1900 Interval I P.T.D. 202-044 Type test P Test psi 1034 Casing 1250 2500 2450 2425 P/F f Notes: Well J-20A Type Inj. S T.V.D. 2959 Tubing 1650 1650 1650 1650 Interval I P.T.D. 200-185 Type test P Test psi 740 Casing 1000 2000 1925 1925 P/F f Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year CYCle s = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to BPXs MPU and witnessed the initial MIT on wells E-13B And J-20A. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was the performed with both wells demonstrating good mechanical integrity. M .1. T. IS performed: ~ Attachments: Number of Failures: Q Total Time during tests: 2 hour cc: M IT report form 5/12/00 L.G. MIT MPU E-13B & J-20A 6-17-02 CS.xls 6/20/2002 ~ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle .- Well MPS-9 d~,OaO MPS-31 å10a.-Q 1t.f MPE-138 ~D~-OYL ~, Job # Log Description 22219 CH EDIT SCMT (PDC) 22218 CH EDIT SCMT (PDC) 22217 CH EDIT SCMT (PDC) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. RECEIVED Anchorage, Alaska 99519-6612 Date Delivered: JUN 0 f~ 2002 Alaska Oil & Gas Cons. Commission Ant'.hrvMA Date 04/26/02 04/26/02 04/24/02 5/22/2002 NO. 2095 Company Alaska 011 & Gas Cons Comm Aftn: Usa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point CD 1 1 1 Color 2 2 2 Sepia BL Schlumberger GeoQuest 3940 Arctic Blvd Anchorage. AK 99503 ATTN: Sherrie ReceiVedbY:~~ 1. Status of Well 0 Oil 0 Gas D Suspended 0 Abandoned 181 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519~6612 4. Location of well at surface "r'v~.,---~:'l:':,'::;; : 3778' NSL, 2067'.W~L, Sec. 25, T13N, R10E, UM ;~1~~r, t'\_":}i:-l~~:: ¡ At top of produc~lve Interval þ' . " 1J i .1:-.b$ - t;~ f 1595 NSL, 1990 WEL, SEC. 23, T13N, R10E, UM 1 .,.,,1,.' ,..... V,~~~', ,',"'. '.,,( At total depth ... ~ .t ~ ~JJ: ,~, 1718' NSL, 2154' WEL, Sec. 23, T13N, R10E, UML",,,,wy,,,;.;\*..,,.;,,w=-:::í, 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 59' ADL 047437 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/30/2002 4/1/2002 4/25/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8852 4432 FT 8765 4356 FT 181 Yes D No 22. Type Electric or Other Logs Run MWD, GR, RES, USIT 23. CASING SIZE 20" 13~3/8" 9-518" WT. PER FT. 91.1# 68# 47# 26# 7" ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well Water Injection 7. Permit Number 202-044 8. API Number 50- 029-22536-02 9. Unit or Lease Name Milne Point Unit 10. Well Number MPE-13Bi 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1800' (Approx.) GRADE NT60 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 32' 112' 30" 250 sx Arctic Set I (Approx.) 31' 2506' 16",1335 sx PF 'E', 250 sx Class 'G' 30' 2506' 12-1/4" 1000 sx Class 'G' 31' 8850' 8-1/2" 355 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 SPf MD TVD 8660' - 8680' 8720' - 8740' 4386' - 4391' 4402' - 4407' 27. Date First Production April 27, 2002 Date of Test Hours Tested 25. TUSING RECORD DEPTH SET (MD) 7821' PACKER SET (MD) 7781' SIZE 2-7/8", 6.5#, L-80 MD TVD 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected 2-7/8" x 7" Annulus with 86 Bbls Diesel and the 7" x 9-5/8" Annulus with 53 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BsL TEST PERIOD CHOKE SIZE GAS-OIL RATIO GAs-McF WATER-BsL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BsL GAs-McF WATER~BsL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or :w,at~r>.o<,S~bT~ CO(~ ?~,ips. . . I ,I - ¡ : \.., ~ ;., ,"',- "1:..""" .28. No core samples were taken. Form 10-407 Rev. 07-01-80 ,{1.b':;:C:ì U:~ J, ': .<":1 ;¡,,:J::<:¡u¡ J:\(:C},~:l':::':;C: . <1 ,R B DMS B F l MAY 3 I 20~bmit In Duplicate ~~ ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF2-NA 8100' 4224' SBF1- NB 8183' 4231' SBE4-NC 8268' 4277' SBE3-ND 8327' 4295' SBE2-NE 8358' 4305' SBE1-NF 8519' 4348' TSBD-OA 8639' 4380' TSBC 8772' 4416' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Integrity Test and a Post Rig Work Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~J\.J\t;l ... ~ Title Technical Assistant MPE-13Bi 202-044 Well Number Permit No. / Approval No. Date (JS. ( 7.~ Prepared By Name/Number: Sandra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 (""~ l) r ~ 'I ~"'''''''''''ID Legal Name: MPE-13 Common Name: MPE-13 Test Date 3/28/2002 3/29/2002 FIT FIT Test Type Test Depth (TMD) (ft) 2,506.0 (ft) Test Depth (TV D) (ft) 2,418.0 (ft) AMW (ppg) 8.80 (ppg) Suñacé. Pressure (psi) 420 (psi) Leak OffPres~u~e (BHP) (psi) 1,525 (psi) EMW (ppg) 12.14 (ppg) .~ _I Printed: 4/8/2002 8:35:32 AM ) ") BP EXPLORATION ()pe~ations S,tlmmäly Rep,ort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-13 MPE-13 REENTER+COMPLETE NABORS NABORS 270 Start: 3/25/2002 Rig Release: 4/5/2002 Rig Number: 27E Spud Date: 2/4/1995 End: 4/5/2002 (jlate From ~ To Hours ActiVityçode NPT Phase Description ofOþeråtioos 3/25/2002 19:00 - 20:00 1.00 MOB P PRE BLOW DOWN RIG 20:00 - 22:30 2.50 MOB P PRE DISCONNECT - MOVE - PUMP - MOTOR - PIT COMPLEX TO E-PAD 22:30 - 00:00 1.50 MOB P PRE INSTALL GOOSE NECK ON PIPE SHED 3/26/2002 00:00 - 01 :00 1.00 MOB P PRE MOVE PIPE SHEDS OUT 01 :00 - 03:30 2.50 MOB P PRE MOVE SUB COMPLEX OFF H-07 03:30 - 07:00 3.50 MOB P PRE MOVE TIRES IN - PREPARE TO MOVE SUB WHILE MOVING PIPE SHEDS - PUMP ROOM COMPLEX'S TO E-PAD 07:00 - 10:00 3.00 MOB P PRE MOVE SUB COMPLEX TO E-PAD - REMOVE DOVE TAIL 10:00 - 12:00 2.00 RIGU P PRE SPREAD TIRES ON SUB - SET MATTING BOARDS 12:00 - 16:00 4.00 RIGU P PRE SPOT SUB COMPLEX OVER E-13 WELL 16:00 - 17:00 1.00 RIGU P PRE SET MATS - SPOT 1ST SECTION OF PIPE SHED 17:00 - 18:30 1.50 RIGU P PRE SET MATS - SPOT PIT COMPLEX - HOOK UP HIGH PRESSURE SHOCK HOSES 18:30 - 20:00 1.50 RIGU P PRE SET MATS - SPOT MOTOR COMPLEX - HOOK UP LINES 20:00 - 21 :00 1.00 RIGU P PRE SET MATS - SPOT PUMP ROOM COMPLEX - HOOK UP SERVICE LINES 21 :00 - 22:00 1.00 RIGU P PRE SET MATS - SET 2ND SECTION OF PIPE SHED 22:00 - 00:00 2.00 RIGU P PRE INSTALL ELECTRIC LINES - SET FUEL TANK - SET HOT AIR HEATER - HOOK UP LINES - WORK ON BERMS 3/27/2002 00:00 - 07:00 7.00 RIGU P PRE WORKING ON BERMS - CIRCULATE STEAM - WATER - AIR THROUGH SYSTEMS (ACCEPT RIG @ 07:00 HRS 3/27/2002) 07:00 - 09:00 2.00 BOPSUR P INT1 ND TREE 09:00 - 16:00 7.00 BOPSURP INT1 INSTALL 135/8 5K X 135/8 5K DRLG SPOOL - NU BOP'S 16:00 - 17:30 1.50 BOPSUR P INT1 RIG UP TO TEST BOP'S 17:30 - 18:00 0.50 BOPSUR P INT1 SPUD MEETING ON MPE-13Bi 18:00 - 21 :30 3.50 BOPSUR P INT1 BOP TEST - ANNULAR 250 LOW MINS 2500 HIGH 5 MINS - TOP RAMS - CHOKE MANIFOLD - HCR KILL - HCR MANUAL - MANUAL KILL - MANUAL CHOKE - 250 LOW 5 MINS 3500 HIGH 5 MINS - TEST GOOD - LOWER PIPE RAMS - NO TEST ON LOW TEST PRESSURE 21 :30 - 23:00 1.50 BOPSUR N SFAL INT1 OPEN RAMS DOORS ON LOWER PIPE RAMS TO INSPECT RAMS - RAM RUBBERS GOOD - CLOSE DOORS - RETEST - NO TEST 23:00 - 00:00 1.00 BOPSURN SFAL INT1 OPEN DOORS ON LOWER 5" RAMS - INSPECT RAMS - TOP SEALS BAD ON BOTH SIDES 3/28/2002 00:00 - 00:30 0.50 BOPSUR N SFAL INT1 CLOSE BOTTOM 5" RAM DOORS. 00:30 - 03:30 3.00 BOPSUR P INT1 TESTED BLIND RAMS AND ALL FLOOR VALVES 250 PSI LOW FOR 5 MINUTES AND 3500 PSI HIGH FOR 5 MINUTES. CHANGED SAVER SUB FROM 3-1/2" TO 5". TEST UPPER AND LOWER IBOP VALVES AND TOPDRIVE. 03:30 - 04:00 0.50 BOPSURN SFAL INT1 CHANGED BOTTOM RAMS IN BOP STACK. 04:00 - 04:30 0.50 BOPSUR P INT1 TEST BOTTOM RAMS TO 250 PSII 3500 PSI FOR 5 MINUTES. BLOW DOWN MANIFOLD. 04:30 - 05:00 0.50 BOPSUR P INT1 PULL TEST PLUG AND INSTALL WEAR RING. OD 13-3/8" ID 8-718" 1.04' LONG. 05:00 - 11 :30 6.50 BOPSUR P INT1 PICKED UP USED 8-1/2" BIT AND 30 JTS OF HWDP. SINGLED IN HOLE WITH 5" DRILL PIPE FROM PIPE SHED 11 :30 - 12:30 1.00 BOPSURP INT1 PULLED OUT OF HOLE AND STRAPPED PIPE IN DERRICK. TAGGED CIBP AT 2528'. 12:30 - 16:00 3.50 BOPSUR P INT1 PU 5" DP FROM PIPE SHED - RIH TO 2528' Printed: 4/8/2002 8:35:40 AM ) ) BP EXPLORAtJON , . Operations'Sutnm~rY RepÐrt . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-13 MPE-13 REENTER+COMPLETE NABORS NABORS 270 Start: 3/25/2002 Rig Release: 4/5/2002 Rig Number: 27E Spud Date: 2/4/1995 End: 4/5/2002 Qate From- To HoL(rs Activity Côde . N PT" Phase. Description af Operåtions 3/28/2002 16:00 - 17:00 1.00 BOPSUR P INT1 PULLED OUT OF HOLE - (44 STDS IN DERRICK) 17:00 - 20:00 3.00 BOPSUR P INT1 PU 5" DP FROM PIPE SHED - RIH TO 2528' 20:00 - 21 :00 1.00 BOPSURP INT1 DISPLACE HOLE WITH MILLING FLUID - @ 560 GPM 21 :00- 22:00 1.00 BOPSUR P INT1 PULLED OUT OF HOLE - (71 STDS IN DERRICK) 22:00 - 00:00 2.00 BOPSUR P INT1 PU 5" DP FROM PIPE SHED - RIH TO 2046' 3/29/2002 00:00 - 01 :30 1.50 STWHIP P INT1 PULLED OUT OF HOLE FROM 2068' AND STAND IN DERRICK. 01 :30 - 02:00 0.50 STWHIP P INT1 HELD PJSM ON PICKING UP AND RUNNING WHIPSTOCK. 02:00 - 06:00 4.00 STWHIP P INT1 PICKED UP WHIPSTOCK, MILLING ASSEMBLY, MWD AND 9 DRILL COLLARS. 06:00 - 07:00 1.00 STWHIP P INT1 TRIP IN HOLE WITH 5" DRILL PIPE SLOWLY. 07:00 - 07:30 0.50 STWHIP P INT1 ORIENT WHIPSTOCK 81 DEGREES TO THE RIGHT. SET WHIPSTOCK. SHEARED SCREW WITH 35K DOWN WEIGHT. MILL ROTATED FREELY. RECORDED SLOW PUMP RATES. TOP OF WINDOW 2506'. 07:30 - 19:00 11.50 STWHIP P INT1 MILLED WINDOW FROM 2506' - 2522' - DRILL FROM 2522' TO 2542' - GPM 400, PP 770 - RPM 90 AT 5000 FTLBS TORQUE, PU WEIGHT 130K, SO WEIGHT 125K. 19:00 - 19:30 0.50 STWHIP P INT1 PREFORM FIT - MUD WEIGHT 8.8 - SURFACE PRESSURE 420 PSI- TVD 2418 = 12.1 FIT 19:30 - 20:00 0.50 STWHIP P INT1 PUMP DRY JOB - BLOW DOWN TOP DRIVE - KILL LINE 20:00 - 20:30 0.50 STWHIP P INT1 POH FROM 2506' TO HWDP 20:30 - 23:00 2.50 STWHIP P INT1 LAY DOWN 25 JOINTS HWDP - 9 STEEL DC'S - MWD - MILLING EQUIPMENT 23:00 - 00:00 1.00 STWHIP P INT1 CLEAN FLOOR OF TOOLS - RIG SERVICE 3/30/2002 00:00 - 01 :30 1.50 DRILL P PROD1 WASHED METAL CUTTINGS OUT OF STACK. 01 :30 - 03:30 2.00 DRILL P PROD1 MADE UP BHA #1 - PICKED UP REBUILT HYCALOG DS70 PDC BIT AND MOTOR SET AT 1.5 DEGREES - MADE UP REST OF BHA - SHALLOW TEST MWD. 03:30 - 04:30 1.00 DRILL P PROD1 TRIPPED IN HOLE WITH 5" DRILL PIPE TO 2,430' 04:30 - 05:00 0.50 DRILL P PROD1 ORIENT TOOLFACE 80 DEGREES TO THE RIGHT - WORKED THROUGH WINDOW - TOP OF WINDOW 2,506' AND BOTTOM OF WINDOW 2,522' - AT 2,522' STRING TOOK 20K OF WEIGHT THEN FELL OFF - RIH TO 2,527' - PULLED BACK UP TO 2,518' AND TOOL AGAIN SAT DOWN AT 2,522' WITH 20K - PICKED UP 2,517' ROTATED 1/4 TURN TO RIGHT - RAN IN HOLE TO 2,522' WEIGHT INDICATOR BOBBLED AND THE STRING WENT THROUGH AND RAN IN HOLE TO 2,542'. 05:00 - 15:00 10.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 2,542' TO 4,028' - WOB 5K TO 10K - RPM 95 - GPM 475 - PP 1450 - TQ 6K - PU 110K - SO 100K - ROT 105K 15:00 - 15:30 0.50 DRILL P PROD1 CBU 30' OFF BOTTOM - PUMPING 474 GPM - 95 RPM - 1350 PP 15:30 - 17:30 2.00 DRILL P PROD1 PUMP OUT FROM 4,028' TO 2,424' - (PULLED TIGHT AT 2,670' 20K OVER - REAM 10' - WORK THROUGH DID NOT SEE ANY OVER PULL) - WORK THROUGHSECTION FROM 2,522' TO 2,518' TAKING WEIGHT GOING IN 20K - ORIENT MOTOR TO 11 OR PULL TO 2,424' FOR RIG MAINTANCE - NO PROBLEMS 17:30 - 18:30 1.00 DRILL P PROD1 RIG SERVICE - CHANGE OIL IN TOP DRIVE 18:30 - 19:30 1.00 DRILL P PROD1 RIH FROM 2,424' TO 4,028' - TOOK 1 OK TO 15K AT 2,522' - HOLE IN EXCELLENT SHAPE Printed: 4/8/2002 8:35:40 AM ) ) BP EXPLORATION Pcage 3 of 5 Operâti,ons, Summary; Repo,rt, Legal Well Name: MPE-13 Common Well Name: M PE-13 Spud Date: 2/4/1995 Event Name: REENTER+COMPLETE Start: 3/25/2002 End: 4/5/2002 Contractor Name: NABORS Rig Release: 4/5/2002 Rig Name: NABORS 270 Rig Number: 27E Date 'FrÒrTl- To Hours ActivityÇoq~;'NPT Phase ' Descriptionbf Operations 3/30/2002 19:30 - 00:00 4.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 4,028' TO 4,686' - WOB 10K TO 15K - RPM 95 - TO 7K TO 8K - GPM 470 - PP 1500 - PU 125K - SO 950K - ROT 110K 3/31/2002 00:00 - 12:30 12.50 DRILL P PROD1 DRILL FROM 4,686' TO 6,564' - PU 135 - SO 95 - ROT 110 - RPM 95 - TO 6K - GPM 475 - PP 1600/1850 - WOB 10K TO 15K 12:30 - 13:30 1.00 DRILL P PROD1 PUMPED HI-VIS SWEEP - CIRCULATE AROUND 13:30 - 15:30 2.00 DRILL P PROD1 ATTEMPT TO PULL OUT OF HOLE - WELL APPEARED TO SWAB - PUMPED OUT OF HOLE TO 4,873' WITH 400 GPM - GAS BREAKING OUT IN BELL NIPPLE AT SURFACE 15:30 - 16:00 0.50 DRILL P PROD1 CIRCULATE OUT GAS CUT MUD - NO GAIN AT SURFACE- OBSERVE WELL - WELL STATIC 16:00 - 16:30 0.50 DRILL P PROD1 RIH FROM 4,873' TO 6,564' - NO PROBLEMS - PROPER MUD DISPLACEMENT 16:30 - 18:30 2.00 DRILL P PROD1 CIRCULATE BOTTOMS UP - GPM 500 - RPM 100 - PP 1600- MUD CUT FROM 9.0+ TO 8.5 PPG WITH BOTTOMS UP - RAISE MUD WEIGHT TO 9.3 PPG 18:30 - 21 :00 2.50 DRILL P PROD1 PUMP OUT FROM 6,564' TO 6,002' - PULL FROM 6,002' TO 4,778' - HOLE TAKING PROPER FILL - PUMP OUT FROM 4,778' TO 4,496' TIGHT HOLE - ACTING LIKE SWAB - PACK OFF - PUMP PRESSURE INCREASE 150 TO 200 PSI- BACK REAM FROM 4,496' TO 4,030' - PULL FROM 4,030' TO 3,554' - NO SWAB OR OVERPULL - HOLE TAKING PROPER FILL- MONITOR WELL - WELL STABLE 21 :00 - 21 :30 0.50 DRILL P PROD1 RIG SERVICE - CHANGE OUT BOOT IN FLOW LINE 21 :30 - 23:30 2.00 DRILL P PROD1 RIH FROM 3,554' TO 6,564' - HOLE IN EXCELLENT SHAPE - NO PROBLEMS ON TRIP IN - FILL PIPE EVERY 10 STANDS 23:30 - 00:00 0.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 6,564' TO 6,752' - WOB 10K TO 15K - TO 8K TO 10K - GPM 475 - PP 1600/1850 - PU 135K- SO 95K - ROT 11 OK - ON BOTTOMS UP GAS CUT MUD TO SURFACE - FLOW INCREASED FROM 31 % TO 62% - NO PIT INCREASE - MUD CUT FROM 9.3+ TO 8.3 PPG -1600 STKS AFTER BOTTOMS UP BEFORE MUD COMING BACK STARTED TO RAISE FROM 8.4 PPG - ADDITIONAL 600 STKS BEFORE RETURNS WERE 9.3 PPG - CONTINUE DRILLING AHEAD - PUMP TWO HI-VIS SWEEPS BACK TO BACK 4/1/2002 00:00 - 18:30 18.50 DRILL P PROD1 DRILL FROM 6564' - 8852'. PUMPING 475 GPM. CONTROL DRILL AT 200'/HR from 7600' to 8852' TO REDUCE HIGH DRILL GAS. PU 175K SO 90K ROT 135K WOB 20K TOROUE 12-14,000 FTLBS AT 99 RPM. PUMPING SWEEPS AS REOUIRED FOR HOLE CLEANING. 18:30 - 20:30 2.00 DRILL P PROD1 CIRCULATE 10,000 STKS - WEIGHT UP TO 9.5 PPG WHILE CIRCULATING - 85 RPM - TO 17K - GPM 475 - PP 1750 20:30 - 23:00 2.50 DRILL P PROD1 PUMP OUT FROM 8852' TO 6595' - PULL FROM 6595' TO 6032' - NO SWAB - NO TIGHT SPOTS - HOLE TAKING CORRECT FILL ON 5 STANDS PULLED 23:00 - 23:30 0.50 DRILL P PROD1 MONITOR WELL FOR FLOW - WELL STATIC 23:30 - 00:00 0.50 DRILL P PROD1 RIH FROM 6032' TO 8099' - NO PROBLEMS - PROPER DISPLACEMENT VOLUME ON TRIP IN - 11.8 BBLS PER 5 STANDS 4/2/2002 00:00 - 00:30 0.50 DRILL P PROD1 RUN IN HOLE FROM 8099' TO 8852'. NO PROBLEMS. 00:30 - 04:30 4.00 DRILL P PROD1 PUMPED HIGH VIS SWEEP AND CIRCULATED 4 Printed: 4/8/2002 8:35:40 AM ) ) BPi EXPLORATION.. OpeFationsS.ummal1' Report, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-13 MPE-13 REENTER+COMPLETE NABORS NABORS 270 Start: 3/25/2002 Rig Release: 4/5/2002 Rig Number: 27E Spud Date: 2/4/1995 End: 4/5/2002 Date, Fronf- To fiour$ ,,' Activity 'Çode NPT Phâse D~~()riþtion'of Op~r~tions 4/2/2002 00:30 - 04:30 4.00 DRILL P PROD1 BOTTTOMS UP. RECIPROCATED 70' STROKES AND ROTATED 70 RPM. PUMPING 450 GPM AT 1550 PSI. 04:30 - 09:00 4.50 DRILL P PROD1 PUMPED OUT OF HOLE FROM 8852' TO 6000' WITH 400 GPM. PULLED OUT OF HOLE FROM 6000' TO 5500' WITHOUT PUMPING. HOLE TAKING CORRECT FILL. PUMPED SLUG AND PULLED OUT OF HOLE TO 2500'. NO PROBLEMS PULLING THROUGH WHIPSTOCK. TOP OF WHIPSTOCK 2506'. RACKING ALL 5" DRILL PIPE IN DERRICK. 09:00 - 09:30 0.50 DRILL P PROD1 OBSERVED WELL FOR 30 MINUTES-NO FLOW. 09:30 - 11 :00 1.50 DRILL P PROD1 PULLED OUT OF HOLE WITH 5" DRILL PIPE. 11 :00 - 13:30 2.50 DRILL P PROD1 LAY DOWN BHA. ADJUST MOTOR TO ZERO. DOWNLOAD MWD. BREAK BIT. 13:30 -14:00 0.50 CASE P PROD1 PULLED WEAR RING. 14:00 - 15:00 1.00 CASE P PROD1 RIGGED UP CASING TOOLS AND MADE UP FILL UP TOOL. 15:00 - 15:30 0.50 CASE P PROD1 HELD PJSM ON RUNNING CASING. 15:30 - 00:00 8.50 CASE P PROD1 RUNNING 7" 26# L-80 BTC CSG TO 8585 WENT TRU WINDOW NO PROBLEMS, ACTING LIKE COLLARS WERE HANGING UP EVERY 40 to 80 FT FROM 4980 DOWN 8550 PICK UP WT 250,000 SLACK OFF 70,000, TOTAL JTS RUN 210 4/3/2002 00:00 - 00:30 0.50 CASE P PROD1 CONTINUED RUNNING IN HOLE WITH 7" CASING TO 8852'. RAN A TOTAL OF 217 JTS OF 7" 26# 1-80 BTC CASING. 00:30 - 02:30 2.00 CASE P PROD1 CIRCULATE AND RECIPROCATE 25' PUMPING 52 SPM AT 650 PSI. PU 250K SO 75K. CIRCULATED 2 BOTTOMS UP WITH NO GAS CUT MUD. 02:30 - 03:30 1.00 CASE P PROD1 RIGGED DOWN FILL UP TOOL AND RIGGED UP CEMENTING HEAD 23' ABOVE ROTARY TABLE. 03:30 - 05:00 1.50 CASE P PROD1 CIRCULATE AND CONDITON MUD 52 SPM AT 650 PSI. UNABLE TO WORK PIPE. PULLED 350K PIPE STUCK 2' OFF BOTTOM AT 8850'. 05:00 - 06:00 1.00 CEMT P PROD1 HELD PJSM. PUMPED 10 BBLS OF WATER, TEST LINE TO 3500 PSI, PUMP 10 BBLS WATER. PUMPED 50 BBLS OF 10.5 PPG ALPHA SPACER. MIIXED AND PUMPED 355 SXS (73 BBLS) PREMIUM CEMENT +0.2% CFR-3 + 0.2% HALAD 344 + .05 GAUSX OF D-AIR + 1% CALCIUM CHLORIDE AT 15.8 PPG AND WITH A YEILD OF 1.15 CFT/SX. 06:00 - 07:30 1.50 CEMT P PROD1 WASH LINES. KICK OUT TOP PLUG AND DISPLACE WITH 9.6 PPG BRINE. PUMPED A TOTAL OF 335 BBLS OF BRINE AND BUMPED PLUG WITH 2000 PSI AT 1720 HRS. CHECKED FLOATS-FLOATS HELD. 07:30 - 08:30 1.00 CEMT P PROD1 BLOW DOWN HALLIBURTON. DRAIN STACK AND RIGGED DOWN CEMENTING LINE. OPENED CEMENTING HEAD. MONITOR WELL. 08:30 - 13:30 5.00 BOPSURP PROD1 RIGGED DOWN CEMENTING HEAD. BROKE ALL BUT 4 BOLTS ON BOTTOM OF DRILLING SPOOL. REMOVED VARIBLE BORE RAMS FROM TOP OF STACK AND INSTALLED 2-7/8" SOLID RAMS. RIGGED UP SLINGS FOR PICKING UP STACK. 13:30 - 15:00 1.50 BOPSUR. P PROD1 SET SLIPS WITH 100K CUT CSG 15:00 - 20:00 5.00 BOPSUR P PROD1 RIG UP TUBING SPOOL AND NIPPLE UP BOPS, TEST TUBING SPOOL TO 4000# FOR 10 MIN. Printed: 4/8/2002 8:35:40 AM ) BR EXPLORATION '. , Operations SUlrunæuyR.eport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-13 MPE-13 REENTER+COMPLETE NABORS NABORS 270 Datß' Fro.rn-Tó Hours ActiyityCode NPT Phase 4/3/2002 20:00 - 21 :00 1.00 BOPSURP PROD1 21 :00 - 21 :30 0.50 BOPSURP PROD1 21 :30 - 22:00 0.50 BOPSUR P PROD1 22:00 - 00:00 2.00 BOPSURP PROD1 00:00 - 00:30 0.50 CASE P PROD1 00:30 - 02:30 2.00 RUNCOIVP CaMP 02:30 - 12:00 9.50 RUNCOIVP CaMP 4/4/2002 12:00 - 13:00 1.00 RUNCOIVP CaMP 13:00 - 15:00 2.00 RUNCOIVP CaMP 15:00 - 20:00 5.00 RUNCOIVP CaMP 20:00 - 20:30 0.50 RUNCOIVP CaMP 20:30 - 22:30 2.00 RUNCOIVP CaMP 4/5/2002 22:30 - 00:00 00:00 - 01 :00 CaMP CaMP 1.50 RUNCOIVP 1.00 RUNCOIVP 01 :00 - 02:00 1.00 RUNCOIVP CaMP 02:00 - 02:30 0.50 RUNCOIVP CaMP 02:30 - 03:30 1.00 RUNCOIVP CaMP 03:30 - 15:00 11.50 RIGD P CaMP 15:00 - 17:00 2.00 RIGD P CaMP ) page>5 .of5; Start: 3/25/2002 Rig Release: 4/5/2002 Rig Number: 27E Spud Date: 2/4/1995 End: 4/5/2002 pØ~cription ofOp~r~tions . RIG DOWN CSG EQUIPMENT SAFETY MEETING WITH JIM DENNEY PRESSURE TEST BOPS BODY TO 3500 FOR 5 MIN. PULL TEST PLUG AND RIG UP TO TEST CSG TO 4500# FOR 30 MIN. TESTED CASING TO 4500 PSI FOR 30 MINUTES. GOOD TEST. BLED OFF PRESSURE. FLUSH CHOKE AND KILL LINES. RIGGED UP 2-7/8" TOOLS FOR RUNNING COMPLETION. PICKED UP TAIL PIPE ASSEMBLY AND BAKERLOCKED. MADE UP BAKER MODEL S-3 PRODUCTION PACKER AND 'X' NIPPLE ASSEMBLY AND RAN IN HOLE WITH 174 JOINTS OF 2-7/8" TUBING. MADE UP AN ADDITIONAL 'X' NIPPLE ASSEMBLY AND PICKED AN ADDITIONAL 71 JTS OF 2-7/8" TUBING. RAN A TOTAL OF 245 JTS OF 2-7/8" 6.5# L-80 EU 8RD TUBING. MADE UP TUBING HANGER AND LANDED TUBING AT 7820.56 '. RAN IN LOCK DOWN SCREWS. UP WEIGHT 80K SO WEIGHT 60K (BLOCK WEIGHT 50K). RIGGED UP TO REVERSE IN INHIBITED BRINE. REVERSE CIRCULATE 210 BBLS OF 9.6 PPG INHIBITED BRINE AT 2.5 BPM AT 420 PSI. BLOW DOWN LINES. INSTALL TWC, NIPPLE DOWN BOP & NIPPLE UP TREE RIG UP AND TEST TREE TO 5000# FOR 10 MIN. FREEZE PROTECT 27/8 X 7 ANNULUS WITH 86 BBLS DIESEL MAX PRESSURE 1100 PSI 2.5 BBLS MIN AND 7X 9 5/8 ANNULUS WITH 53 BBLS DIESEL MAX PRESSURE 1450 PSI 2.5 BBLS MIN. U-TUBE 2 7/8 x 7", DROP BALL TO SET PACKER WAIT ON BALL TO SEAT. PRESSURED UP TO 3500 PSI TO SET PACKER. HELD PRESSURE TEST ON TUBING TO 3500 PSI AND HELD ON CHART FOR 30 MINUTES. GOOD TEST. BLED PRESSURE ON TUBING TO 2000 PSI. PRESSURE TEST ANNULUS TO 3500 PSI FOR 30 MINUTES AND RECORDED ON CHART. GOOD TEST. BLED PRESSURE ON TUBING AND CASING TO ZERO. RIGGED DOWN HB&R. INSTALLED BPV IN TUBING HANGER AND SECURED WELL. HELD PJSM ON LAYING DOWN 5" DRILL PIPE. INSTALLED MOUSE HOLE IN ROTARY TABLE AND SECURED TO TREE. LAID DOWN 5" DRILL PIPE FROM DERRICK. SLIP AND CUT DRILL LINE. RELEASED RIG AT 1700 HRS 4-05-2002. Printed: 4/8/2002 8:35:40 AM Well: Field: API: Permit: ) ') MPE-13B Milne Point Unit I Schrader Bluff 50-029-22536-02 202-044 Rig Accept: 03/27/02 Rig Spud: 03/30102 Rig Release: 04/05/02 Drilling Rig: Nabors 27E POST RIG WORK 04/15/02 Pulled BPV. Pulled RHC plug, drifted tbg wi 2" dummy gun to 7810' slm just out of the tubing tail. Tried again with 10' of roller stem instead of dummy gun and the deepest was 8370' slm. Ran a sample bailer below roller stem and could only get to 8370' again. Bailer empty. 04/24/02 MIRU DS CTU #2, Rih wi SCMT. Tag SSV, damage tool. Rih wi spare SCMT, loose communication at -3200'. Pooh. Change cartridge & centralizer. Rih wi spare SCMT. Log from PBTD to 8423' ctmd for comparison pass. Log from PBTD to 7700'. POOH. Field quick look: good cement 8260' - 8320' and 8350' - 84081, OK to marginal cement from 8408' and below. 04/25/02 RIH wi gun #1. Attempt to shoot, no indication of shot. POOH. Guns did not fire. Re-run gun #1. Shoot - 211 PJ, 4spf 8720' - 8740' ELMD. POOH, guns fired. RIH wi gun #2. Shoot 211 PJ 4 SPF 8660' - 8680'. POOH, guns fired. MIRU DS CTU #2, Rih wi SCMT. ~Oð JOLlY ') 18-Apr-02 AOGCC Attn: Lisa Weepie 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Definitive Re: Distribution of Survey Data for Well MPE-13B Dear Sir I Madam: Enclosed are 2 survey hard copy(s) and 1 disk. Tie-on Survey: Window I Kickoff Survey Projected Survey: 2,505.00 'MD 2506.00 I MD 8852.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, RECEIVED William T. Allen Survey Manager l P;) 1 C) 2002 ' 'I ¡ \ ,- AfaakaOiJ & Gas Cons. Commission Anchorage Attachment(s) DEFNITIVE Milne Point Unit BPXA Milne Point MPE, Slot MPE-13 MPE-138 Job No. AKZZ22054, Surveyed: 1 April, 2002 _J SUR VE Y R E P 0 R T 18 April, 2002 Your Ref: API 500292259702 Surface Coordinates: 6016315.01 N, 569071.36 E (70° 27'17.7645- H, 149" 26' 10.6400" W) Kelly Bushing: 59.0Dft above Mean Sea Level '---/ sf...tê=I'JIV-SUf1 DRILLÎNti SEÀvU::es A Halliburton Company Survey Ref: 5vy10109 ;'i~~.i~:~.~~'(. . . . . '{q~~~ ,. Sperry-Sun Drilling Services' '. 'MJ Survey Report for MPE-13B DEJ:/NITIVE BPXA Your Ref: API 500292259702 Job No. AKZZ22054, Surveyed: 1 April, 2002 Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/100ft) 2505.00 28.450 285.550 2381.68 2440.68 152.57 N 339.82 W 6016464.43 N 568736.14 E 369.26 Tie On Point AK-6 BP _IFR-AK 2506.00 28.450 285.550 2382.56 2441.56 152.70 N 340.28 W 6016464.55 N 568735.68 E 0.011 369.72 Window Point 2551.32 29.890 286.300 2422.14 2481.14 158.77 N 361.52 W 6016470.42 N 568714.39 E 3.278 390.97 2644.54 36.960 287.530 2499.89 2558.89 173.75 N 410.60 W 6016484.94 N 568665.17 E 7.619 440.59 ~... 2737.99 41 .720 288.490 2572.14 2631.14 192.08 N 466.91 W 6016502.75 N 568608.69 E 5,135 498.13 2833.76 45.710 289.020 2641.35 2700.35 213.36 N 529.56 W 6016523.46 N 568545.84 E 4.184 562.61 2926.63 49.740 285.560 2703.82 2762.82 233.71 N 595.16 W 6016543.20 N 568480.06 E 5.140 629,10 3020.54 55.410 285.200 2760.87 2819.87 253.48 N 667.04 W 6016562.29 N 568408.00 E 6.045 700,63 3114.67 59.500 281 .710 2811.51 2870.51 271.88 N 744.19W 6016579.98 N 568330.68 E 5.351 775.92 3208.28 64.870 283.550 2855.17 2914.17 290.01 N 824.94 W 6016597.36 N 568249.77 E 5.994 854.13 3303.20 69.740 286.710 2891.79 2950.79 312.89 N 909.42 W 6016619.46 N 568165.07 E 5,979 938.02 3397.5fi ]1,820 287.790 2921.29 2980.29 339.48 N 995.00 W 6016645.25 N 568079.26 E 4.458 1024.78 3490.90 73.570 288.300 2947.50 3006.50 367.23 N 1080.18 W 6016672.21 N 567993.82 E 0.589 1111.82 3585.00 73.410 287.770 2974.24 3033.24 395.16 N 1165.96 W 6016699.34 N 567907.78 E 0.566 1199.47 3678.81 73.400 287.320 3001.03 3060.03 422.26 N 1251.68 W 6016725.65 N 567821.81 E 0.460 1286,62 3774.36 73.820 290.300 3028.00 3087.00 451.81 N 1338.44 W 6016754.40 N 567734.78 E 3.024 1375.96 3870.30 74.480 295.070 3054.22 3113.22 487.40 N 1423.57 W 6016789.19 N 567649.34 E 4.832 1467.07 3966.28 76.170 300.980 3078.55 3137.55 531.02 N 1505.47 W 6016832.05 N 567567.03 E 6.211 1559,67 4058.22 75,180 301.780 3101.30 3160.30 577.40 N 1581.52 W 6016877.73 N 567490.55 E 1.368 1648.75 4151.15 74,040 301.560 3125.96 3184.96 624.45 N 1657.78 W 6016924.06 N 567413.86 E 1.248 1738.35 "-- 4246.60 76.030 303.990 3150.61 3209.61 674.36 N 1735.30 W 6016973.26 N 567335.89 E 3.224 1830.53 4339.59 77.090 305.300 3172.22 3231.22 725.78 N 1809.70 W 6017023.98 N 567261.01 E 1.782 1920.86 4427.69 76.720 304.810 3192,18 3251.18 775.07 N 1879.94 W 6017072.61 N 567190.31 E 0.685 2006.52 4525.76 76,070 304.800 3215.25 3274.25 829.47 N 1958.21 W 6017126.29 N 567111.55 E 0,663 2101,70 4622.94 75.190 304.310 3239.37 3298.37 882.87 N 2035.74 W 6017178.97 N 567033.52 E 1.029 2195.73 4714.71 74.760 304.650 3263.16 3322.16 933.04 N 2108.80 W 6017228.46 N 566960.00 E 0.590 2284.26 4810.59 74.560 304.490 3288.53 3347.53 985.51 N 2184.94 W 6017280.22 N 566883.38 E 0.263 2376.61 4901.21 74.060 304.220 3313.03 3372.03 1034.74 N 2256.96 W 6017328.78 N 566810.90 E 0.622 2463.76 4996.82 73.700 304.570 3339.58 3398.58 1086.63 N 2332.75 W 6017379.96 N 566734.63 E 0.515 2555.51 5090.86 73.430 304.170 3366.19 3425.19 1137.55 N 2407.20 W 6017430.19 N 566659.71 E 0.499 2645.62 - --- --~-------- 18 April, 2002 - 14:21 Page 20f5 DrillQuest 2,00.09.003 "::'"': -, ~-. '~~~~~_. . .' Sperry-Sun Drilling Services~J~~~~:: Survey Report for MPE-138 Your Ref: API 500292259702 Job No. AKZZ22054, Surveyed: 1 April, 2002 BPXA Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) eft) eft) eft) eft) (°/1 OOft) 5184.84 72.570 304.140 3393.66 3452.66 1188.01 N 2481.57 W 6017479.96 N 566584.88 E 0.916 2735.41 5279.04 75.050 304.120 3419.93 3478.93 1238.76 N 2556.45 W 6017530.01 N 566509.53 E 2.633 2825.79 5373.75 74.740 304.580 3444.61 3503.61 1290.35 N 2631.94 W 6017580.90 N 566433.57 E 0.572 2917.13 5469.54 74.480 304.690 3470.03 3529.03 1342.84 N 2707.93 W 6017632.69 N 566357.09 E 0.293 3009.37 5561.66 73.180 304.400 3495.68 3554.68 1393.01 N 2780.81 W 6017682.18 N 566283.76 E 1.443 3097.73 _. 5656.73 75.830 305.080 3521.08 3580.08 1445.22 N 2856.08 W 6017733.68 N 566208.00 E 2.871 3189.21 5750.82 75.840 305.310 3544.10 3603.10 1497.80 N 2930.63 W 6017785.57 N 566132.97 E 0.237 3280.28 5844.29 75.160 305.370 3567.51 3626.51 1550.14 N 3004.45 W 6017837.23 N 566058.67 E 0.730 3370.59 5939.37 74.570 304.640 3592.33 3651.33 1602.79 N 3079.63 W 6017889.18 N 565983.01 E 0.967 3462.22 6032.87 73,790 304.760 3617.82 3676.82 1654.00 N 3153.59 W 6017939.70 N 565908.58 E 0.843 3552.06 6126.78 73.250 304.110 3644.46 3703.46 1704.92 N 3227.86 W 6017989.93 N 565833.84 E 0.878 3642.01 6218.93 76.050 303.830 3668.85 3727.85 1754.57 N 3301.55 W 6018038.89 N 565759.69 E 3,053 3730.80 6312.09 76.110 30tt.160 3691.26 3750.26 1805.13 N 3376.52 W 6018088.75 N 565684.25 E 0.350 3821.15 6406.96 75.350 303.860 3714.65 3773.65 1856.55 N 3452.73 W 6018139.47 N 565607.57 E 0.858 3913.02 6501.50 74.000 304.560 3739.63 3798.63 1907.81 N 3528.13 W 6018190.03 N 565531.69 E 1.597 4004,11 6589.05 74.820 304.580 3763.16 3822.16 1955.66 N 3597.57 W 6018237.23 N 565461.81 E 0.937 4088.34 6689.48 75.060 303.850 3789.26 3848.26 2010.19 N 3677.77 W 6018291.02 N 565381.11 E 0.741 4185.23 6782.76 75.190 303.280 3813.20 3872.20 2060.04 N 3752.89 W 6018340.17 N 565305.53 E 0.607 4275.34 6876.80 75.410 303.580 3837.07 3896.07 2110.15N 3828.80 W 6018389.57 N 565229.16 E 0.387 4366.26 6971.38 75.030 303.450 3861.20 3920.20 2160.65 N 3905.05 W 6018439.36 N 565152.45 E 0.423 4457.66 7066.32 75.190 303.430 3885.59 3944.59 2211.21 N 3981.61 W 6018489.21 N 565075.42 E 0.170 4549.38 7161.35 74.840 303.370 3910.16 3969.16 2261.74 N 4058.25 W 6018539.03 N 564998.32 E 0.373 4641. 14 7255.63 73.9ttO 303.290 3935.53 3994.53 2311.63 N 4134.11 W 6018588.21 N 564921.99 E 0.958 4731.90 7349.80 73.590 303.400 3961.86 4020.86 2361.33 N 4209.64 W 6018637.21 N 564846.00 E 0.388 4822.28 7443.65 73.410 303.040 3988.52 4047.52 2410.63 N 4284.92 W 6018685.81 N 564770.27 E 0.415 4912.24 7537.16 74.290 305.530 4014.53 4073.53 2461.23 N 4359.13 W 6018735.71 N 564695.60 E 2.725 5001.96 7631.10 76.200 306.950 4038.46 4097.46 2514.93 N 4432.39 W 6018788.74 N 564621.85 E 2.504 5092.51 7726.00 75.930 306.900 4061.31 4120.31 2570.26 N 4506.02 W 6018843.39 N 564547.70 E 0.289 5184.24 7820,17 74.910 306.780 4085.01 4144.01 2624.91 N 4578.96 W 6018897.35 N 564474.26 E 1.090 5275,02 7914.46 73,630 307.770 4110.58 4169.58 2679.87 N 4651.18 W 6018951.64 N 564401.54 E 1.692 5365,35 ---- --- 18 April, 2002 - 14:21 Page 3 of 5 DrillQuest 2.00,09.003 .6~perry-Sun Drilling Servicer-t .. Survey Report for MPE.13B Your Ref: API 500292259702 Job No. AKZZ22054, Surveyed: 1 April, 2002 BPXA Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8006.23 73.130 307.290 4136.83 4195.83 2733.44 N 4720.91 W 6019004.56 N 564331.31 E 0.740 5452.84 8101.76 72.490 307.690 4165.06 4224.06 2788.98 N 4793.32 W 6019059.43 N 564258.38 E 0.780 5543.64 8195.88 71.410 307.630 4194.22 4253.22 2843.66 N 4864.17 W 6019113.45 N 564187.04 E 1.149 5632.65 8288.95 70.610 307.270 4224.51 4283.51 2897.17 N 4934.03 W 6019166.31 N 564116.68 E 0.934 5720.22 8383.32 73.910 305.740 4253.26 4312.26 2950.62 N 5006.27 W 6019219.09 N 564043.95 E 3.823 5809.78 8478.73 75.190 307.380 4278.68 4337.68 3005.40 N 5080.13 W 6019273.18 N 563969.58 E 2.132 5901.41 8573.45 74.490 306.930 4303.45 4362.45 3060.62 N 5153.00 W 6019327.72 N 563896.21 E 0.870 5992.42 8667.70 74.070 307.250 4328.98 4387.98 3115.33 N 5225.37 W 6019381.76 N 563823.33 E 0.553 6082.75 8758.55 74.220 307.310 4353.80 4412.80 3168.27 N 5294.90 W 6019434.05 N 563753.31 E 0.177 6169.74 8791.20 74.130 306.650 4362.71 4421.71 3187.16 N 5320.00 W 6019452.71 N 563728.04 E 1.964 6201,02 8852.00 74,130 306.650 4379.33 4438.33 3222.07 N 5366.92 W 6019487.18 N 563680.80 E 0.000 6259.29 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.0610 (27-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 301.740° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8852.000., The Bottom Hole Displacement is 6259.84ft., in the Direction of 300.979° (True). '--'"-- ----------- 18 April, 2002 - 14:21 Page 4 0'5 DriflQuest 2.00.09.003 Milne Point Unit Comments Measured Depth (ft) 2505.00 2506.00 8852.00 , " ~~;2' Sperry-Sun Drilling Service~;'~~" Survey Report for MPE-13B Your Ref: API 500292259702 Job No. AKZZ22054, Surveyed: 1 April, 2002 . 152.57 N 152.70 N 3222.07 N Survey tool program for MPE-13B BPXA Milne Point MPE Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2440.68 2441.56 4438.33 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 2505.00 18 April, 2002 - 14:21 0.00 2440.68 To Measured Vertical Depth Depth (ft) (ft) 2505.00 8852.00 Comment 339.82 W 340.28 W 5366.92 W Tie On Point Window Point Projected Survey Survey Tool Description 2440.68 AK-1 BP _HG (MPE-13) 4438.33 AK-6 BP _IFR-AK (MPE-13B) - _.--_._--~- Page 50'5 DrillQuest 2.00.09.003 ) AOGCC Attn: Lisa Weepie 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 ) Re: Distribution of Survey Data for Well MPE-138 MWD Dear Sir / Madam: Enclosed are 2 survey hard copy(s) and 1 disk. Tie-on Survey: Window / Kickoff Survey Projected Survey: 2,505.00'MD 2506.00 I MD 8852.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ~. :---, ,. ;'-- " .; () r:.'1("'-' ¡ '. ;., ~ :J :~~II¿ Alaska Oil & Gas Cons t't '. Anchorage \.iOmmlSSion ~è::d-04L/ 18-Apr-02 Milne Point Unit BPXA Milne Point MPE, Slot MPE-13 MPE-13B MWD Job No. AKMW22054, Surveyed: 1 April, 2002 SURVEY REPORT 18 April, 2002 Your Ref: API 500292259702 Surface Coordinates: 6016315.01 N, 569077.36 E (70° 27' 17.7645" N, 149026' 10.6400" W) Kelly Bushing: 59.0Off above Mean Sea Level !SpE!I .. .Y-!!!IL.I! D"IL~INCI '-""VI. d A HaHlburton Company ""../ Survey Ref: 5vy10110 Sperry-Sun Drilling Services . Survey Report for MPE-13B MWD Your Ref: API 500292259102 Job No. AKMW22054, Surveyed: 1 April, 2002 BPXA Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2505.00 28.450 285.550 2381.68 2440.68 152.57 N 339.82 W 6016464.43 N 568736.14 E 369.26 Tie On Point MWD Magnetic .~. 2506.00 28.450 285.550 2382.56 2441.56 152.70 N 340.28 W 6016464.55 N 568735.68 E 0.011 369.72 Window Point 2551.32 29.890 286.300 2422.14 2481.14 158.77 N 361.52 W 6016470.42 N 568714.39 E 3.278 390.97 2644.54 36.960 282.160 2499.90 2558.90 171.21 N 411.28 W 6016482.39 N 568664.51 E 7.965 439.83 2737.99 41 .720 288.430 2572.18 2631.18 186.97 N 468.30 W 6016497.63 N 568607.35 E 6.631 496.62 2833.76 45.710 287.990 2641.39 2700.39 207.64 N 531.15 W 6016517.71 N 568544.30 E 4.178 560,95 2926.63 49.740 280.350 2703.90 2762.90 224.29 N 597.71 W 6016533.75 N 568477.60 E 7.470 626.31 3020.54 55.410 279.890 2760.95 2819.95 237.38 N 671.10W 6016546.16 N 568404.09 E 6.050 695.61 3114.67 59.500 280.150 2811.57 2870.57 251.19 N 749.22 W 6016559.24 N 568325.84 E 4.351 769.31 3208.28 64,870 283.950 2855.25 2914.25 268.53 N 830.12 W 6016575.83 N 568244.78 E 6.766 847.24 3303.20 69.740 287.380 2891.87 2950.87 292.20 N 914.39 W 6016598.72 N 568160.30 E 6.118 931.35 3397.56 73.820 289.630 2921.37 2980.37 320.66 N 999.35 W 6016626.39 N 568075.08 E 4.881 1018.58 3490.90 73.570 289.310 2947.58 3006.58 350.52 N 1083.81 W 6016655.47 N 567990.34 E 0.424 1106.12 3585.00 73.410 288.800 2974.32 3033.32 379.98 N 1169.09 W 6016684.13 N 567904.80 E 0.547 1194.14 3678.81 73.400 288.320 3001.11 3060.11 408.59 N 1254.32 W 6016711.96 N 567819.31 E 0.490 1281.67 3774.36 73.820 289.880 3028.07 3087.07 438.59 N 1340.93 W 6016741.15 N 567732.42 E 1.627 1371.12 3870.30 74.480 294.570 3054.29 3113.29 473.49 N 1426.34 W 6016775.26 N 567646.69 E 4.753 1462.11 3966.28 76.170 300.800 3078.63 3137.63 516.62 N 1508.50 W 6016817.62 N 567564.13 E 6.521 1554.67 "-' 4058.22 75.180 302.110 3101.38 3160.38 563.10 N 1584.49 W 6016863.40 N 567487.72 E 1.751 1643.75 4151.15 74.040 302.100 3126.04 3185.04 610.72 N 1660.39 W 6016910.31 N 567411.38 E 1.227 1733,34 4246.60 76.030 304.830 3150.69 3209.69 661.57 N 1737.29 W 6016960.45 N 567334.01 E 3.461 1825.50 4339.59 77.090 307.150 3172.31 3231.31 714.72 N 1810.46 W 6017012.91 N 567260.35 E 2.681 1915.69 4427.69 76.720 307.320 3192.27 3251.27 766.64 N 1878.78 W 6017064.20 N 567191.55 E 0.460 2001.10 4525.76 76.070 307.250 3215.33 3274.33 824.38 N 1954.62 W 6017121.23 N 567115.18 E 0.666 2095.97 4622.94 75.190 306.890 3239.45 3298.45 881.13 N 2029.73 W 6017177.28 N 567039.55 E 0.974 2189.70 -- ---- . ------ 18 April, 2002 - 12:52 Page 2 0'5 DrlllQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPE-138 MWD Your Ref: API 500292259702 Job No. AKMW22054, Surveyed: 1 April, 2002 BPXA Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinate. Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 4714.71 74.760 307.540 3263.24 3322.24 934.73 N 2100.32 W 6017230.23 N 566968.47 E 0.829 2277.93 4810.59 74.560 306.230 3288.61 3347.61 990.23 N 2174.27 W 6017285.04 N 566894.00 E 1.334 2370.02 -- 4901.21 74.060 305.810 3313.12 3372.12 1041.53 N 2244.83 W 6017335.69 N 566822.97 E 0.710 2457.02 4996.82 73.700 305.380 3339.66 3398.66 1095.00 N 2319.52 W 6017388.45 N 566747.79 E 0.573 2548.66 5090.86 73.430 304.240 3366.27 3425.27 1146.49 N 2393.58 W 6017439.25 N 566673.26 E 1.198 2638.73 5184.84 72.570 305.120 3393.75 3452.75 1197.62 N 2467.48 W 6017489.70 N 566598.88 E 1 .280 2728.48 5279.04 75.050 303.510 3420.01 3479.01 1248.61 N 2542.20 W 6017539.99 N 566523.69 E 3.102 2818.85 5373.75 74.740 304.120 3444.69 3503.69 1299.49 N 2618.17W 6017590.17 N 566447.26 E 0.703 2910.22 5469.54 74.480 300.900 3470.12 3529.12 1349.12 N 2696.04 W 6017639.08 N 566368.93 E 3.252 3002.56 5561.66 73,180 303.320 3495.78 3554.78 1396.14 N 2770.97 W 6017685.40 N 566293.56 E 2.891 3091.02 5656.73 75.830 303.130 3521 .17 3580.17 1446.33 N 2847.61 W 6017734.88 N 566216.47 E 2.794 3182.60 5750.82 75.840 303.710 3544.20 3603.20 1496.58 N 2923.75 W 6017784.42 N 566139.86 E 0.598 3273,79 5844.29 75.160 304.280 3567.60 3626.60 1547.18 N 2998.78 W 6017834.32 N 566064.37 E 0.937 3364.21 5939.37 74.570 305.220 3592.43 3651.43 1599.49 N 3074.19W 6017885.93 N 565988.47 E 1.138 3455.86 6032.87 73.790 304.080 3617.92 3676.92 1650.64 N 3148.19 W 6017936.39 N 565914.00 E 1.439 3545.70 6126.78 73.250 305.990 3644.56 3703.56 1702.33 N 3221.92 W 6017987.39 N 565839.79 E 2.033 3635.60 6218.93 76.050 305.280 3668.95 3727.95 1754.09 N 3294.14 W 6018038.49 N 565767.10 E 3.128 3724.25 6312.09 76.110 305.430 3691.36 3750.36 1806.42 N 3367.89 W 6018090.12 N 565692.87 E 0.169 3814.49 6406.96 75.350 305.750 3714.75 3773.75 1859.92 N 3442.65 W 6018142.94 N 565617.61 E 0.865 3906.23 ~ 6501.50 74.000 304.900 3739.73 3798.73 1912.64 N 3517.04 W 6018194.96 N 565542.74 E 1.671 3997,22 6589.05 74.820 306.410 3763.26 3822.26 1961.80 N 3585.56 W 6018243.48 N 565473.77 E 1.907 4081.35 6689.48 75.060 304.410 3789.36 3848.36 2017.99 N 3664.60 W 6018298.94 N 565394.21 E 1.938 4178.13 6782.76 75.190 302.930 3813.31 3872.31 2067.97 N 3739.62 W 6018348.22 N 565318.72 E 1.540 4268.23 6876.80 75.410 302.770 3837.17 3896.17 2117.31 N 3816.04 W 6018396.85 N 565241.85 E 0.286 4359.17 6971.38 75.030 303.710 3861.30 3920.30 2167.44 N 3892.53 W 6018446.26 N 565164.90 E 1.042 4450.59 7066.32 75.190 304.430 3885.70 3944.70 2218.84 N 3968.53 W 6018496.96 N 565088.43 E 0.752 4542,27 7161.35 74.840 304.730 3910.27 3969.27 2270.94 N 4044.11 W 6018548.35 N 565012.37 E 0.478 4633,95 7255.63 73.940 305.850 3935.64 3994.64 2323.39 N 4118.23 W 6018600.12 N 564937.77 E 1.490 4724.58 7349,80 73.590 302.110 3961.97 4020.97 2373.92 N 4193.18 W 6018649.95 N 564862.35 E 3.831 4814.90 7443.65 73.410 302.370 3988.63 4047.63 2421.92 N 4269.29 W 6018697.24 N 564785.79 E 0.328 4904.89 ----~--~-- 18 April, 2002 - 12:52 Page 3 0'5 DrllfQuest 2.00.08,005 Sperry-Sun Drilling, Services . Survey Report for MPE.138 MWD Your Ref: API 500292259702 Job No. AKMW22054, Surveyed: 1 April, 2002 BPXA Milne Point Unit Milne Point MPE Measu red Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eaetlng. Northing. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7537.16 74.290 306.130 4014.65 4073.65 2472.47 N 4343.52 W 6018747.10 N 564711.10 E 3.975 4994.60 7631.10 76.200 306.300 4038.57 4097.57 2526.14 N 4416.81 W 6018800.09 N 564637.32 E 2.041 5085.16 ~ 7726.00 75.930 308.350 4061.43 4120.43 2581.98 N 4490.05 W 6018855.25 N 564563.57 E 2.116 5176.82 7820.17 74.910 307.450 4085.13 4144.13 2637.96 N 4561.96 W 6018910.56 N 564491.14 E 1.424 5267.43 7914.46 73.630 309.210 4110.70 4169.70 2694.24 N 4633.15 W 6018966.18 N 564419.43 E 2.252 5357.59 8006.23 73.130 308.000 4136.95 4195.95 2749.11 N 4701.87 W 6019020.41 N 564350.20 E 1.376 5444.89 8101.76 72.490 310.040 4165.18 4224.18 2806.56 N 4772.77 W 6019077.20 N 564278.77 E 2.147 5535.41 8195.88 71.410 307.940 4194.35 4253.35 2862.87 N 4842.32 W 6019132.86 N 564208.71 E 2.412 5624.18 8288,95 70.610 306.580 4224.63 4283.63 2916.15 N 4912.36 W 6019185.49 N 564138.18 E 1.627 5711.77 8383.32 73.910 307.560 4253.38 4312.38 2970.33 N 4984.06 W 6019239.00 N 564065.98 E 3.634 5801.25 8478.73 75.190 308.190 4278.80 4337.80 3026.79 N 5056.65 W 6019294.78 N 563992.87 E 1 .485 5892.68 8573.45 74.490 307.040 4303.57 4362.57 3082.59 N 5129.06 W 6019349.91 N 563919.94 E 1.385 5983.62 8667.70 74.070 308.250 4329.11 4388.11 3138.00 N 5200.90 W 6019404.65 N 563847.59 E 1.314 6073.86 8758.55 74.220 307.340 4353.93 4412.93 3191.55 N 5269.96 W 6019457.56 N 563778.04 E 0.978 6160.77 8791.20 74.130 307.760 4362.83 4421.83 3210.70 N 5294.86 W 6019476.48 N 563752.96 E 1.268 6192.02 8852.00 74.130 307.760 4379.46 4438.46 3246.51 N 5341.10 W 6019511.86 N 563706.39 E 0.000 6250.18 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. - Magnetic Declination at Surface is 26.0610 (27 -Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 301.740° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8852.0Oft., The Bottom Hole Displacement is 6250.37ft., in the Direction of 301.293° (True). 18 April, 2002 - 12:52 Page 4 0'5 DrlllQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPE-13B MWD Your Ref: API 500292259702 Job No. AKMW22054, Surveyed: 1 April, 2002 . Milne Point Unit BPXA Milne Point MPE Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) Comment 2505.00 2506.00 8852.00 2440.68 2441.56 4438.46 152.57 N 152.70 N 3246.51 N 339.82 W 340.28 W 5341.10 W Tie On Point Window Point Projected Survey Survey tool program for MPE-13B MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 2505.00 0.00 2440.68 2505.00 8852.00 2440.68 AK-1 BP _HG (MPE-13) 4438.46 MWD Magnetic (MPE-13B MWD) '-" -------~~ 18 April, 2002 - 12:52 Page 50f5 DrmQuest 2.00.08.005 ) ~~A~E : F !Æ~!Æ~~~A ,~ ) ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. "pH AVENUE, SUITE 100 ANCHORAGE" ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Schultz Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit :MPE-13Bi BP Exploration (Alaska), Inc. Permit No: 202-044 Sur. Loc. 3778' NSL, 2067' WEL, Sec. 25, TI3N, RI0E, UM Btmhole Loc. 1737' NSL, 2250' WEL, Sec. 23, TI3N, RI0E, UM Dear Mr. Schultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point Unit :MPE-13Bi. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, 0./r1Mv~~" QU-l¡,,(' ~<'f/ Cammy gechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 1st day of March, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA STATE OF ALASKA )L AND GAS CONSERVATION COMt\ PERMIT TO DRILL 20 AAC 25.005 ~6Æ sf¡to'L, ¥ 'l310N .J1\Â t-t 3/ô1J~~J,/ A'}/ t 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3778' NSL, 2067' WEL, Sec. 25, T13N, R10E, UM At top of productive interval 1601' NSL, 2035' WEL, SEC. 23, T13N, R10E, UM At total depth 1737' NSL, 2250' WEL, Sec. 23, T13N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025518,1737' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 2480' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casing Weight Grade CouolinQ LenÇJth 7" 26# L-80 BTC 8918' 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil 181 Service 0 Development Gas li'Single Zone ÄÞ 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned KBE = 59' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 047437 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-13Bi 9. Approximate spud date 03/15/02 J/ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8951' MD / 4441' TVD 0 17. Anticipated pressure {s,¡e 20 AAC 25.035 (e) (2)} 75 Maximum surface 1505 psig, At total depth (TVD) 4305' / 1936 psig Setting Depth T(lp Botom Quantity of Cement MD TVD MD TVD lincludj staae data) Surface Surface 89511 4441' 224 sx Class IG' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Hole 8-1/2" Casing Structural Conductor Surface Intermediate Production Liner 16350 feet 8801 feet 8500 feet 7181 feet Length Plugs (measured) ø~'O,~ ~<i'iC; C\ ~ .~~~ ,~ ~ ~ t)~~ Bridge plug set at 8500' M \.. \,~ CJ~r..,9 I C2;rfJ ~~~ ~~~Q ~~ M~fr TVD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Junk (measured) Size Cemented 80' 20" 250 sx Arcticset 1 (approx) 112' 112' 5162' 133/8" 1335 sx PF 'E'/250 sx 'G' 5193' 4813' 12805' 9 5/8" 1000 sx Class 'G' 12835' 8803' 3748' 41/2" Uncemented Slotted Liner 12580' - 16328' 8718' - 8802' 20. Attachments Above Bridge Plug: 8220' - 8246'; 8260' - 8270' Slotted Section, Below Bridge Plug: 12876' - 16326' true vertical Above Bridge Plug: 7076' - 7086', 7092' - 7096' Slotted Section, Below Bridge Plug: 8814' - 8802' 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 MC 25.050 Requirements Contact Engineer NameINumber: James Franks, 56 ,-44 Steve Campbell, 564-4401 21. I hereby certify that the fO~QoJng~s tru a co ect to the best of my knowledge Signed Steve Shultz / /~ Title Senior Drilling Engineer -, Commi.sionUsé On~y." Prepared By NameINumber: Sandra Stewman, 564-4750 Perforation depth: measured Date 2J"2!Ó~ Permit Number ,API Number Approval Date See cover letter 2() 2- -Ò t.,I t/ 50- 029-22536-02 for other requirements Conditions of Approval: Samples Required 0 Yes (H'No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes ~ No Directional Survey Required (gYes 0 No JWYYJ Required Working Pressure for BOPE D2K D3K D4K 0 5K 0 10K 0 15K ~ 3.5K psr~ Other: \.J\\ '\ ~ <:"Cc...~\.~\ ~~~\\\'i \c~ Original Signed By lr .) by order of Approved By Cammy Oecl1sli Commissioner the commission Form 10-401 Rev. 12-01-85 ' f , t ll'< L..~ Date Submit In Triplicate 02/26/02 08:40 FAX 907 564 5193' ßPEXPLOHNI'ION -') AOGCC ) B f )oration (Alaska) Inc, 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp TO: Steve Davies COMPANY: Alaska 011 & Gas Conservation Commission ~ " ,,,,,~,,,,,.,.,..," ".. -,-"""","'''''''''' ,- -",,,,,,~....,,. ."'...,.,.,,, "."""~."."",,..... .-'" , .-....... ,.".." .~.",.' ",."".", LOCATION: Anchorage FAX #: 276-7542 FROM: Terrie Hubble GPB Well Delivery LOCATION: ANCHORAGE, ALASKA I4J 0 OJ .. .."'''' ""~"" "0,.,,,......,... ~. ,'-", "'"" PHON E #: 564...4628 , --"..' ." ,.."",,,,,, PAGES TO FOLLOW: DATE: 02-26..02 2 - , " "'~',1l..",.".....,,,, ",,,""""""'.' COMMENTS: IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER: f) r~ ¡-., ¡,'.' '~ ,fl r~ r< [ f:~::: '1:.' [: (907) 564-4628 '.. ,". -"I'''¡ , H~J~'/ 6 ,i.\ìaska OJ¡ & G(¡~) Ccn~< t/ü~mnj~ijIU Anchorê¡Q8 .,~ ~f.'" ... -~. ~~. ~ ._.~",,~-,- . ') 0 ).Ç) ~~ <:(O'~ ~,\.~f(., ( ~ \. " 3 . 8 . . 2 1°+ TBD+ 13+ 9+ 15+ TBD+ . 4 .1 .5 . 6 . 7 +TBD . ,-:..:/ NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.999905434. 3. HORIZONTAL/VERTICAL CONTROL IS BASED ON MONUMENTS CFP-3 AND E-1. 4. ELEVATIONS ARE MILNE POINT DATUM M.S.L. 5. REFERENCE FIELD BOOK: MP94-02 (pgs.59-62). 6. DATE OF SURVEY: SEPTEMBER 20, 1994. LEGEND + AS-BUILT WELLS . EXISTING WELLS..,,--., ,. LOCATED WITHIN PROTRACTED SEC. 25, T. 13 N.~ R. 10 L, U.M., AK. , WELL A.S.P. PLANT GEODETIC CELLAR SECTION- NO. COORDINATES COORDINATES POSITION BOX ELEV. OFFSETS Y= 6,016,268.46 N. 2130.09 70.27'17.303" 3731' FSL 9 X= 569.-115.42 E. 1292.11 149.26'09.535" 24.3' 2029' FEL TSD y= 6,016,273.49 N.2009.63 70.27'17.335" 24.6' 3735' FSL x= 569,314.15 E.1450.28 149.26'03.695" 1830' F"EL 15 Y= 6,016,221.62 N.2069.84 70.27'16.8389" 24.4' 3684' FSL X= 569,153.31 E. 1292.35 149.26'08.434" 1992' FEL 13 Y= 6,016,315.01 N.2190.22 '. 70.27'17.764" ~4.4' 3778' FSL X= 569,077.36 E. 1291.56 149.26'10.640" 2067' FEL 10 Y=6,016,408.98 N. 2310.23 ~ 70.27'18.695" ~4.7' 3873' FSL X= 569,002.74 E.1292.17 "149.26'12.807" 2141' FEL TSD y= 6,016,175.23 N. 2010.19 70.27'16.379" 24.3' 3637' FSL X= 569,190.80 E. 1292.56 149.26'07.346" 1955' FEL TSD y= 6~016,361.44 N.2249.63 70.27'18.224" 24.4' 3825' FSL . X= 569,040.31 E. 1291.72 149.26'11.716" 2103' FEL '~--) )izPfJ) z~ ~ ,i" ~ ~~FP --- I / "- Y' \ .J'~ E PAD 26 50. ~o ~~IS ~RVEY Z ~ ~ 5~ ~~ 1 T.13N. . ~ Œ.13N. VICINITY MAP N.T.S. f ~ "ff / -~- I SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER 19, 1994. F. R. BELL & ASSOCIATES .",,,BP .EXPLORA TION MILNE POINT UNIT E PAD CONDUCTOR AS-BUILT WELLS 9 THROUGH 15 , ..' DAIle: DRAWN: CHECK: APPROVAL: 9/29/94 FEN TIE GREENWA Y ALLISON 11/19/94 RE-NUMBER WELLS 10-15 PER JOE POL YA JMF HITCH SCALE: "fœf; AH.f; CADD FILE ,: 9/29/94 '''=200' MPEPADAB 0 ORIGINAL AS-BUILT ISSUE JMF RLG .MJf: I SUB Jwf: ORAWHG I: SHU:T: AEVI: REV. DATE REVISIONS DRAWN CHECK MPEPADAB 1 OF 1 1 ~ BPXA ""L..~ ~ J~~ ~~~ Milne Point Unit Milne Point MPE n-=-:lI£)lIeS( ~.;!. MPE-13B Tj.Q.~ ~ I ;;0 . ~ ..., m .. "., >f CD 0 !i ~ m 0';) - I I'V < C> m C> f'",} C ~ """...H......-_^"... .......,........ Scale: 1inch = 750ft -5250 I Eastings (Well Reference) ..{!OOO -2250 I I -750 I -1500 I -4500 I -3750 I fA1IE.l38 TI Top 011 Point T.gøI 4305.00 TVD, 3103.70 No 5248.81 W End Dir. Start Sail @ 73.000" : 8684.79ftMD,4363.80ftTVD Begin Dir @ 5.00001100ft : 8632. 16ft MD, 4349.22ft TVD End Dir, Start Sail @ 74.843": 3850.35ftMD,3098.93ftTVD Tie-on : Start: Dir @ 12.000°/1000: 2480.00ffMD,2418.63ftTVO- 0 - 3750 -3000 en 0 c: IU - 2250 .! (J) a: ãi ~ (/J C) c :¡: ~ - 1500 ~ - 750 _10 ~ \ 0 . 0 N "'- N ~ " N co .þ. -=j >- ~ :.c -.:¡ C11 ~ .þ. C11 ¡..... ¡:.c '-.-' ,c...: gg - .I....o.J >< ~ 0 ::c ~ "'":: - ::z I .J.. .~ 5 § ð 5 II) l"- n -5 ~ ;¡¡ ~ (/J ~ - - ) bp 'xploration (Alaska) Inc, JEast Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RE(EIVED ... ,\.".",. ~~~ ~~. ~..- -~. '4~..~i\' Alaska Oil & Gas Cdns. Commission -"4" Anchorage FEB 26 2002 TO: Steve Davies COMPANY: Alaska Oil & Gas Conservation Commission lOCATION: Anchorage FAX #: 276-7542 FROM: Terrie Hubble GPB Well Delivery lOCATION: ANCHORAGE, ALASKA PHONE #: 564-4628 PAGES TO FOllOW: 2 DATE: 02-26-02 COMMENTS: 005ìM~$ Ei ?----S<&-ts ~Ól-ed ;' IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL THE FOLLOWING NUMBER: (907) 564-4628 ~. 4 ~...., BPXA f',_f~ ".N-, .RVU~.~ Milne Point Unit "''''~tlJl'il~''( 750 - pro 1 500 - Q) u c @ Q) ã> a: ~ 2250 - ..c ã. Q) Q (ij u :e Q) > 3000 - 3750 - 5 LO l"- II or. 0 .£ åj 4500 - (ij 0 en ""_:11_.. - -I. 1"\ ^", ^^ ^^^ ~~~:1~~nt MPE DrillQII~st~ 0 pro MPE-13 B WP-oS Formations Single Well Target Data for MPE-13B Measured Vertical Sub-Sea Measurement lkIits : Depth Depth Depth Dip Dip Dir. Fonnalion Name Coordinate (It) (It) (ft) (Deg) (Deg) Target Point TVD SSTVD Northktgs Easlktgs ASP Northlngs ASP Eastlngs Target 6266.97 3730.80 3672.00 0.000 0,531 Top Ugw-TUlC Name Type Shape 7762.38 4121.80 4063,00 0.000 0.531 Top Ugw M - TI.TlB MPE-13BTl TopOA Entry Point 4363.80 4305J)() 3103.79 N 5248.81 W 6019370,00 N 563800.00 E Point 8095. to 4208,80 4150.00 0.000 0531 SBFl-NA 8206,02 4237,80 4179.00 0,000 0.531 SBFl-NB MPE-13B TargetPoty Entry Point 4363,80 4305.00 3103,79 N 5248.81 W 6019370.00 N 563800.00 E Circle 8297.8t 4261.80 4203.00 0.000 0.531 SBB4-NC 840 1.07 4288,80 4230.00 0.000 0531 SBE2-NE 8573,18 4333.80 4275.00 0.000 0531 SBEI-NF 8684.79 4363.80 4305.00 0.000 0531 TSBl).()A mro MPE-13 B WP-oS Comments Measured Vertical Comment Depth Depth (It) (It) ~. 2480,00 2500J)() 3400.00 385035 8632.16 8684.79 895133 2418.63 2436.26 2979.64 3098.93 4349.22 4363.80 4441.73 TIe-on: SIm Dir @ 12.0000/100ft : 2480.00ftMD,2418.63ft1VD Begin Dir @ 5.156°/l00ft : 2500.00ft MD, 2436.26ft 1VD Continue build 5J)()()°/I00ft End Dir, Start Sail @ 74.843°: 385O.35ftMD,3098,93ftTVD J:\.~ ir_' ! . I.-.-."I!'.IIIIII ~': I. !rll '~1' J.\.J'" .'.Ii !\I_' f..i..!~t.._. :"01'.-:' .\...!!'= '.~I.I.I o,-.,.J ;.'"i'~"I J.II:.I~.III!".~' i .1...1 llti...r. ~ ,<! .' .In_~li' 1.J.J! j ,Hi Ï'.l. 1600ro Current Well Properties WeB: l-bri2DntaI Coordinates: Ref. Global Coordinates : Ref. Structure Reference : Ref. Geographical Coordinates: RKB Elevation : MPE-13B 6016315.01 N, 569077.36 E 2519.59 N, 340.01 W 70° 27' 17.7645' N, 149° 26' 10.6400. W ¡Continue buik! 5.000'/10011 3OO~ , /00 Dir, Start Sail 0 74.843° : 3850,35ftMD.3098.93fITVD _l7oo.oo -4100,00 58.6011 above Mean Sea Level 58.8011 above Structure Reference True I'«>rth Feel (US) I'«>rth Reference : lkIils : -4500.00 ~.oo ~3oo.oo ---' ~7DO.oo Ji1oo.oo -'i'>Oû,oo UPE.l38T1 TopOA 4363.80 TVD, 3103.79 N, 5248.81 W MPE.I3B Target Poly ItrP£. 1 ' 1300.00 4363.80 TVD, . 38 iliA 3103.79 N, 5248.81 W "05 J7oo,oo Radiua: 250.00ft 11100.00 / ' . T Casi"g Begin Dir @ 5.000°/10011: 8632.1611 MO, 4349.22ft TVD -- -"'iOO.oo 8951.33MD - - ¿; 4441.731VD End Dir, Start Sail 0 73,000°: 8684.79ftMD,4363.8OftTVD --- - Ii .00 To1al [lpth : 8951.33ftMD, 4441.73fITVD .ñ9OO.DO 0 Scale: 1 inch = 750ft I 750 I 2250 I I 3000 3750 Vertical Section (Well Reference) I 4500 I I 5250 6000 Section Azimuth: 301.740° (True North) ~. .. V--.., BPXA ~.....(~ 'UJI.~ .--.""HC.. Milne Point Unit "'~~..,.t~.. ~~~~1~~nt MPE DrillQlIest~ Scale: 1 inch = 750ft -5250 I -4500 I -3750 I Eastings (Well Reference ) -3000 -2250 I I -1500 I -750 I 0 MPE,I38 T1 Top OA Point T811111 4305,00 TVD. 3103.79 N. 5248.81 W - 3750 End Dirt Start Sail @ 73.000° : 8684.79ftMD,4363.80ftTVD Begin Dir @ 5.0000/100ft : 8632.16ft MDt 4349.22ft TVD J:tJ --" - 3000 CD <.> c: ~ - 2250 ~ CD a: Q) ~ rJ) C> c: :c t:: - 1500 ~ -" - 750 End Dir, Start Sail @ 74.843° : 3850.35ftMD,3098.93ftTVD Begin Dir @ 5.156°/1000 : 2500.000 MD, 2436.26ft TVD 5 I() ...... II .c 0 .!;; 0 (¡j ãi 0 en "'_:II^... _& n ,..,.. "'" "^^ ) I Well Name: 1M PE-13Bi Drill and Complete Plan Summary Schrad -'luff Pro~nam MPE-13Bi Well Permit I Type of Well (service / producer / injector): I Schrader Bluff Water Injector Surface Location: 1500' FNL, (37781 FSL), 2067' FEL, ( 3211' FWL), SEC. 25, T13N, R10E X=569077.36 Y=6016315.01 ' 36781 FNL, (16011 FSL), 20351 FEL, (32441 FWL), SEC. 23, T13N, R10E X=563800 Y=6019370 Z=4364' TVDrkb 35411 FNL, (17371 FSL), 2250 FEL, (30291 FWL) SEC. 23, T13N, R10E X=563584 Y=6019505 Z=4441' TVDrkb Target Start Location: "OA" Bottom Hole Location: I AFE Number: I TBD I Ria: I Nabors 27E I I Estimated Start Date: I Mar. 15, 2002 I I Operatina days to complete: 111 I I MD: 18951 1 I TVD: 14441 1 1 Max Inc: 174 1 I KOP: 124801 1 KBE: 1591 1 1 I Well Desian (conventional, slimhole, etc.): I Side Tracked Injector I Objective: I Schrader "OA" Mud Program: 25 - 60 LSND Freshwater Mud pH API Filtrate LG Solids < 6.5 9.0-9.5 <8 8-1/2" Production Hole Mud Properties: Density (ppg) Funnel,visc YP HTHP 9.1-9.2 75 - 150 N/A LCM Restrictions: No Organic LCM products in the Schrader Bluff formation / Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU lR. Cement ProQram: Casinç Size 17" 26 lb/ft L-80 BTC Production Longstring casing Basis 140% excess over gauge hole Total Cement Volume: Wash 20 bbl of Newtonian Wash weighted to 8.32 ppg Spacer 50 bbl of Spacer (Alpha Design) weighted to 11.0 ppg Tail 224šxs 15.8lb/gal Prem G 1.15 ê'uft/sx (top of tail at 7595' MD)../ Temp I BRST ~ 800 F from SOR, BHCT 850 F estimated by Halliburton 1 ) )ne Point MPE-13Bi Well Permit Evaluation Program: 8 1/2" Hole Section: Open Hole: MWD/GR/RES Cased Hole: USIT (post rig) Formation Markers: Formation Tops MDrkb (ft) TVDss (ft) Pore Pressure Estimated EMW (Psi) (pPQ) Base Permafrost 1742 1742 SV1 Top Ugnu 6267 3672 1652 8.65 Top Ugnu M 7762 4063 1828 8.65 NA 8095 4150 1867 8.65 NB 8206 4179 1880 8.65 NC 8298 4203 1891 8.65 NE 8401 4230 1903 8.65 NF 8573 4275 1923 8.65 Top OA 8685 4305 1936 8.65 Base OA 4342 1953 8.65 Top OB 4378 1969 8.65 Base OB 4402 1980 8.65 TD 8951 CasinglTubinQ Program: See attached Hole Size Csg / WtlFt Grade Conn Length Tbg O.D. 8 1/2" Tubing 7" 26# L-80 BTC 6.3# 1-80 EUE 8918 ' 7945' Top Bottom MD / TVDrkb M D / TVDrkb Surface 8951' / 4441 ' Surface 7945' /4170' 2 7/8" Recommended Bit ProQram: BHA Hole Depth (MD) Bit Type Size Drilling 8 1/2" KOP' - 8951 ' Nozzle/Flow rate DS70 2 ) )ne Point MPE-13Bi Well Permit Well Control: . Production hole will be drilled with BOP's. Production Interval . Maximum anticipated BHP: . Maximum surface pressure: . Planned BOP test pressure: . Kick tolerance: . Planned completion fluid: 1936 psi @ 4305' TVDss - Top of "OA" 1505 psi @ su rface / (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) ~psi ./ 35c>o (J ¡¡. W§A- . , 11.2 ppg FIT - w/9.2 ppg mud, 8.65 ppg pore. 9.1 ppg KCL / 6.8 ppg Diesel Drilling Hazards & Contingencies: Hydrates . E-Pad has been a difficult pad to predict the presence of gas hydrates. Serious gas cut mud from hydrates was seen between 2,1 OO-ft - 2,480-ft TVDss in four of the 1994 - 1995 wells. These wells were all located in the ESE quadrant of the pad. MPE-13B is in the NW quadrant where no hydrates have yet been encountered. No hydrates were observed when the original MPE-13 well was drilled. The KOP for MPE-13B is at 2,419-ft TVDss, in the potential hydrate zone. Hence, be alert for hydrates. Use recommended practices for drilling hydrates. See Well Program and Recommended Practices for specific information. . Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation . Lost circulation has not been encountered while drilling this interval on previous Milne Point E- Pad wells. . Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures . It is unlikely there will be unexpected overpjBssure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.65 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. This well we be drilled in the drained portion of the MPC-41 fault block. Offset injectors that have above normal shut-in pressures will be shut-in prior to drilling this well. Pad Data Sheet . Please Read the E-Pad Data Sheet thoroughly. 3 ) )ne Point MPE-13Bi Well Permit Breathing . N/A Hydrocarbons / . Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults . -25' fault at or around 5300' MD/3425' TVDss in the Ugnu to the south. . -50' fault at or around 6125' MD/3650' TVDss in the Ugnu to the south. . -30' fault at or around 8075' MD/421 0' TVDss in the N Sand to the south. Hydrogen Sulfide Ii . MPE Pad is not designated as an H2S Pad. Anti-collision Issues . MPE-13Bi has no anti-collision issues. Integrity Testing . MPE-13Bi will be drilled with BOP's - wI 9.2 ppg mud, 8.65 ppg pore. / Test Point 7" shoe Test Depth 20" minimum from 7" shoe Test type EMW(ppg) FIT 11 .2 ppg 4 ') Operations Summary )ne Point MPE-13Bi Well Permit PRE RIG 1. Grade and level pad as needed. 2. MIRU Nabors 4ES.' 3. Circulate the well to KW brine. NO tree. NU stack. Test to 3,500-psi. V'" 4. Pull and lay down 2.a75-in ESP completion / tubing. 5. Abandon the existing wellbore per procedure in Application for Sundry form 403. 6. Set a Baker 9.a75-in BP on 3.5-in DP @ 2,4aO-ft MD. 7. Test casing and retainer to 3,500-psi./ a. Freeze protect well with diesel. POH. 9. Install tubing hanger and BPV. 10. NO BOPE. NU Tree and test to 5,000-psi. 11. RDMO Nabors 4ES. ./ 12. Arctic Pack the 12.375-in x 9.a75-in annulus with 15.6-lb/gal cement. 13. An Ice Extension will need to be built on the SW side of the pad - 40' x 300' PROCEDURE 1. MIRU Nabors 27E. 2. Pull BPV. 3. Set TWC. NO Tree. N~OP. 4. Test BOP to 3,500-psi. Pull TWC. 5. PU Windowmaster Whipstock. RIH. Set on BP. 6. Displace well to drilling fluid. 7. Mill window. POOH. a. MU a.5-in BHA. RIH to window. 9. Drill well to TO; build from 240 to 730 and hold for -6,650-ft. 10. Short trip to window. POOH from TO 11. PU 7.0-in casing. RIH to TO. 12. Pump cement as per plan to set top -500-ft TVD above top of N-sands. 13. PU 2.a75-in tubing. RIH to -7945-ft MD and set packer. 14. Displace well to KW brine. 15. Set TWC. Test from above to 1,000-psi and from below to 200-psi. 16. NO BOP. NU Tree. Test to 5,000-psi. 17. RDMO Nabors 27E. POST RIG 1. RDMO MIRU E-line. 2. Pull TWC. / 3. Run USIT. 4. Perforate the well. 5. Freeze protect. 6. RDMO. 5 TREE: 29/16" - 5M f-h') WELLHEAD: Gen 511" 5f\ 2-7/8" NSCT T&B, 2.5" CIW type 'H' profile ,) v, ,¡,G. KB. ELEV = 53.8' (N27E) ORIG. KB - BF = 28.7' (N27E) GROUND LEVEL = 24.7' Casing landed on FMC Emeraency SIiDS MPE-13A f KOP @ 600' MAX HOLE Angle 93 DEG AT 13,100' MD Cameo 27/8" x 1" I 141' sidepocket KBMM GLM I 5193' I 13 3/8", 68#/ft, L-80 Butt . , Cameo 27/8" x 1" I 7,955' I side pocket KBMM GLM 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift ID = 2.347", cap. = 0.00592 bpf) HES 2-7/8" "XN" Nipple (No-go = 2.205") 8,093' I 9-5/8" 47#/ft., L-80 BTRC, production csg., (Drift 10 = 8.525", cap. = 0.0732 bpf) I 8,108' 1 1 8,126' 1 I 6,955' I 18,131' 1 18,145' I 18,145' I Pump, 159 stg. GC1150, Model GPMTAR1:1 Tandem Gas Separator, Model - GRSTXBARH6 Intake TVD Tandem Seal Section, Model - GST34BILPFS ~"."..."...":..".,.,.",,,'.:.:.....,':,:.'..,.,:,..,.,:"..,.......":.",,,:,':,:, 1':: I * Motor, 114 HP, 2330 V., 30 amp, KMH PumpMate DHP Gauge w/6-fin Centralizer Perforation Summary Ref log: 07/14/01 GRlCCL - - Size SPF Interval (TVD) K (p::lnlk "C" S,;md 4.5" 5 8220'-8226' (7052'-7058') I ~''".'~T;:.~'¡''rl'~1 Howco 9-5/8" VTO Retrievable K(p::lrllk "R" R,~;md Pkr. w/.156" choke 4.5" 5 8226'-8246' (7058'-7075') = ~ 4.5" 5 8260-8270' (7087'-7095') ~ ~~~;i~~werJet Charges - 72 degree r1 T:pO::::::::I:Cker \ \ \ 9518", N-95/L-80, NSCC Shoe \ \ \ \ \ I - - 112,578' I 112,835' I 8 1/2" Horizontal Section I 16,326' I 1 16,348' I Pack Off Sub 4 1/2", 12.6#,NSCT L-80 ---.J L- Horizontal Wellbore: ~~ Slotted liner (3/16" wide) f/12,876' to16,326 DATE REV. BY COMMENTS Mil NF POINT UNIT 8/419! JMK RWO ESP Change out WFI I F-13A 06/30 /97 MOO ESP RWO 4ES API NO: 50-O?9-??536 11 / 07 / 97 BOB RWO ESP Change out 7/14101 GMH Nabors 4ES RWO - ESP C/O and Kuparuk BP EXPLORATION (AK) R....nmnh.t.. I I Estimated TOC 1,900' 15.9 ppg Cement Estimated BOC I 2,650' j , TREE: 29/16" - 5M Fl..) WELLHEAD: Gen 5 11" 51\ 2-7/8" NSCT T&B, 2.5" CIW type 'H' profile MPE-13A KOP @ 600' MAX HOLE Angle 93 DEGAT 13,100' MD 13 3/8", 68#/ft, L-80 Butt I 5193' I 9-5/8" 47#/ft., L-80 STC, production csg., (Drift ID = 8.525", cap. = 0.0732 bpf) Perforation Summary Ref log: 07/14/01 GRlCCL Size SPF Interval (TVD) K ~paruk "C" S~nd 4.5" 5 8220'-8226' (7052'-7058') 4.5" 5 8226'-8246' (7058'-7075') K ~paruk "B" Sand 4.5" 5 8260-8270' (7087'-7095') 4505 PowerJet Charges - 72 degree Phasing , , .~~t~ , t" ' ' \ l \ --U- Horizontal Wellbore: Slotted liner (3/16" wide) f/12,876' to 16,326' ~///A¥>I'M Go ,.2 KB. ELEV = 53.8' (N27E) ORIG. KB - BF = 28.7' (N27E) GROUND LEVEL = 24.7' Casing landed on FMC Emergency ~ 9-5/8" Cement Retainer I 8,170' 15.9 ppg Cement <~'I.~' 9-5/8" Cement Retainer 15.9 ppg Cement 112,528' I Top of TIW Horizontal packer 112,578' I 95/8", N-95/L-80, NSCC Shoe 112,835' I 8 1/2" Horizontal Section Pack Off Sub 41/2", 12.6#,NSCT L-80 I 16,326' I I 16,348' I DATE REV. BY COMMENTS Mil NF POINT UNIT 81419~ JMK RWO ESP Change out WFI I F-13A 06 1 30 / 97 MDO ESP RWO 4ES API NO: 50-0'9."536 11/07/97 BDB RWO ESP Change out 7/14/01 GMH Nabors 4ES RWO . ESP c/o and Kuparuk BP EXPLORATION (AK) Rp,.,nmnlptp TREE: 29/16" - 5M F" ) WELLHEAD: Gen 511" 5ft. 2-7/8" NSCT T&B, 2.5" CIW type 'H' profile MPE-13Bi G. ..} KB. ELEV = 53.8' (N27E) ORIG KB - BF = 28.7' (N27E) GROUND LEVEL = 24.7' Whipstock and window KOP @ 2480MD' --..., Cameo 2 7/8" x 1" ,~ 2300' j , 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift ID = 2.347", cap. = 0.00592 bpf) 9-5/8" 47#/ft., L-80 BTRC, production csg., (Drift ID = 8.525", cap. = 0.0732 bpf) at. ZZ HES 2-7/8" "XN" Nipple (No-go = 2.205") S-3 Packer - = 8685'-8801' :: (4364'-4397') , ~ 7", 26#/ft, L-80 Butt I 8951' I Perforation Summary Ref log: 07/14/01 GRlCCL Size SPF Interval (TVD) K )paruk "C" S~nd 4.5" 5 8220'-8226' (7052'-7058') 4.5" 5 8226'-8246' (7058'-7075') K )paruk "8" S:md 4.5" 5 8260-8270' (7087'-7095') 4505 Power Jet Charges - 72 degree Phasing a ..... .....~ 9-5/8" EZSV ,¡:<~it:,,;~ . . . ' . j~~![\ T:;:8;,:Z:o~zonœl packer . . \ \ \ .. . . . 9 5/8". N-95/L-80, NSCC Shoe \ l \ l \ I 112,578' I 112,835' I 8 1/2" Horizontal Section Horizontal Wellbore: Slotted liner (3/16" wide) f/12,876' to16,326 '/N////~ Pack Off Sub 41/2", 12.6#,NSCT L-80 I 16,326' I I 16,348' I --LJ- DATE 2/1 0/2002 REV. BY JDF COMMENTS Proposed completion Mil NF POINT UNIT WFII F-13Ri API NO: 50-0?Q-?'536 BP EXPLORATION (AK) -- ',-/ "-" .~ Milne Point Unit Alaska ,Drilling & Wells Milne Point MPE, Slot MPE-138 MPE-13a - MPE-13 8 WP-05 Revised: 6 February, 2002 PROPOSAL REPORT 6 February, 2002 ..-1 Surface Coordinates: 6016315.01 N, 569077.36 E (70027' 17.7645" N, 149026' 10.6400" W) Surface Coordinates relative to Project H Reference: 1016315.01 N, 69077.36 E (Grid) Surface Coordinates relative to Structure Reference: 2519.59 N, 340.01 W (True) Kelly Bushing: 58. 80ft above Mean Sea Level ~'=-~rry-EiL...r1 QB]if.;~lBg.IE""lI~Ji~ A kàìtb$ntri ~jIifØ,' ProposalRe~pro10057 '~ '~ -- Sperry-Sun Drilling Services Proposal Report for MPE-13a - MPE-13 B WP-oS Revised: 6 February, 2002 aska Drilling & Wells Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 2480.00 27.933 286.242 2359.83 2418.63 149.37 N 328.55 W 6016461.32 ~t1¡¡'il¡¡¡i.7 47 .44"iË 357.99 Tie-on: Start Dir @ 12.000°/1000 : 2480.00ftMD,2418.63ftTVD 2500.00 28.441 281.274 2377.46 2436.26 151.61 N 337.72 W 6016463.48 N <~¡¡i¡¡!¡¡ßlf8738.25 E 12.000 366.97 Begin Dir @ 5.156°/1000 : 2500.000 MD, 2436.26ft TVD 2600.00 33.596 281.274 2463.13 2521.93 6016473.08 N 568687.64 E 5.156 415.23 ~ 2700.00 38.752 281 .274 2543.82 2602.62 6016484.08 N 568629.67 E 5.156 470.51 2800.00 43.908 281.274 2618.89 2677.69 6016496.39 N 568564.81 E 5.156 532.36 2900.00 49.064 281.274 2687.72 6016509.90 N 568493.58 E 5.156 600.28 3000.00 54.220 281.274 2749.76 6016524.51 N 568416.57 E 5.156 673.72 3100.00 59.376 281.274 2804.50 6016540.10 N 568334.39 E 5.156 752.09 3200.00 64.531 281.274 2851.50 6016556.55 N 568247.71 E 5.156 834.75 3300.00 69.687 281.274 2890.38 6016573.72 N 568157.23 E 5.156 921.03 3400.00 74.843 281.274 2920.84;' 1011.07 W 6016591 .46 N 568063.68 E 5.156 1010.23 Continue build 5.000°/1 OOft 3500.00 74.633 286.452 2947.18' 1104.70W 6016613.70 N 567969.84 E 5.000 1102.01 3600.00 74.542 291.638 2973.77 1195.79W 6016644.30 N 567878.46 E 5.000 1196.02 3700.00 74.572 296.825 3000.42 1283.65 W 6016683.03 N 567790.24 E 5.000 1291 .55 3800.00 74.722 302.008 3026.91 1367.62 W 6016729.59 N 567705.84 E 5.000 1387.86 3850.35 74.843 304.614 3040.13 3098.93 453.96 N 1408.22 W 6016755.90 N 567664.99 E 5.000 1436.43 End Dir, Start Sail @ 74.843° : 3850.35ftM D ,3098.93ftTVD 3900.00 74.843 304.614 3053.11 3111.91 481.18 N 1447.66 W 6016782.75 N 567625.30 E 0.000 1484.29 4000.00 74.843 304.614 3079.26 3138.06 536.01 N 1527.09 W 6016836.84 N 567545.36 E 0.000 1580.69 4100.00 74.843 304.614 3105.40 3164.20 590.84 N 1606.53 W 6016890.93 N 567465.42 E 0.000 1677.09 4200.00 74.843 304.614 3131.55 3190.35 645.67 N 1685.97 W 6016945.02 N 567385.48 E 0.000 1773.48 '- 4300.00 74.843 304.614 3157.70 3216.50 700.50 N 1765.40 W 6016999.11 N 567305.54 E 0.000 1869.88 4400.00 74.843 304.614 3183.84 3242.64 755.33 N 1844.84 W 6017053.20 N 567225.60 E 0.000 1966.28 4500.00 74.843 304.614 3209.99 3268.79 810.16N 1924.28 W 6017107.29 N 567145.66 E 0.000 2062.68 4600.00 74.843 304.614 3236.14 3294.94 864.99 N 2003.71 W 6017161.38 N 567065.71 E 0.000 2159.08 4700.00 74.843 304.614 3262.28 3321.08 919.82 N 2083.15 W 6017215.47 N 566985.77 E 0.000 2255.48 4800.00 74.843 304.614 3288.43 3347.23 974.64 N 2162.58 W 6017269.56 N 566905.83 E 0.000 2351.88 4900.00 74.843 304.614 3314.58 3373.38 1029.47 N 2242.02 W 6017323.65 N 566825.89 E 0.000 2448.28 5000.00 74.843 304.614 3340.73 3399.53 1084.30 N 2321.46 W 6017377.74 N 566745.95 E 0.000 2544.68 5100.00 74.843 304.614 3366.87 3425.67 1139.13 N 2400.89 W 6017431.83 N 566666.01 E 0.000 2641 .08 5200.00 74.843 304.614 3393.02 3451.82 1193.96 N 2480.33 W 6017485.92 N 566586.07 E 0.000 2737.48 6 February, 2002 - 15:01 Page2of6 DrillQuest 2.00.09.008 "- .~ ~ Sperry-Sun Drilling Services Proposal Report for MPE-13a - MPE-13 B WP-DS Revised: 6 February, 2002 aska Drilling & Wells Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft), ' 5300.00 74.843 304.614 3419.17 3477.97 1248.79 N 2559.77 W 6017540.01 N 5Gs506.13:;e;' 0.000 2833.88 5400.00 74.843 304.614 3445.31 3504.11 1303.62 N 2639.20 W 6017594.10 N 566426.18 E 0.000 2930.28 5500.00 74.843 304.614 3471.46 3530.26 1358.45 N 2718.64 W 6017648.19 N 566346.24 E 0.000 3026.68 5600.00 74.843 304.614 3497.61 3556.41 1413.28 N 2798.07 W 601770228 N 566266.30 E 0.000 3123.08 5700.00 74.843 304.614 3523.75 3582.55 1468.10 N 2877.51 W 6017756.37 N 566186.36 E 0.000 3219.48 .~ 5800.00 74.843 304.614 3549.90 3608.70 2956.95 W 6017810.46 N 566106.42 E 0.000 3315.88 5900.00 74.843 304.614 3576.05 3634.85 3036.38 W 6017864.55 N 566026.48 E 0.000 3412.28 6000.00 74.843 304.614 3602.19 3660.99 3115.82 W 6017918.64 N 565946.54 E 0.000 3508.68 6100.00 74.843 304.614 3628.34 3687.14 . ;;,9195.26 W 6017972.73 N 565866.60 E 0.000 3605.08 6200.00 74.843 304.614 3654.49 3713.29 <P3274.69 W 6018026.82 N 565786.65 E 0.000 3701.48 6266.97 74.843 304.614 3672.00 37¡$Ø. 3327.89 W 6018063.05 N 565733.12 E 0.000 3766.04 Top Ugnu -TUZC 6300.00 74.843 304.614 3680.64 313'g. 3354.13 W 6018080.91 N 565706.71 E 0.000 3797.88 6400.00 74.843 304.614 3706.78 3765.58 3433.57 W 6018135.00 N 565626.77 E 0.000 3894.28 6500.00 74.843 304.614 . .3732.93 "~791 ;7ß' 3513.00 W 6018189.09 N 565546.83 E 0.000 3990.68 6600.00 74.843 304.61.4-' 3759.08 ~j 7.88 3592.44 W 6018243.18 N 565466.89 E 0.000 4087.08 6700.00 74.843 . 304;614 3785.22 3844.02 2016.39 N 3671 .87 W 6018297.27 N 565386.95 E 0.000 4183.48 6800.00 74.843 ' 304J314 381;1137 3870.17 2071.22 N 3751.31 W 6018351.36 N 565307.01 E 0.000 4279.88 6900.00 74.843 .304.614 3837.52 3896.32 2126.05 N 3830.75 W 6018405.45 N 565227.07 E 0.000 4376.28 7000.00 14.843 , 304.614 3863.66 3922.46 2180.88 N 3910.18 W 6018459.54 N 565147.12 E 0.000 4472.68 7100.00 74.843 304.614 3889.81 3948.61 2235.71 N 3989.62 W 6018513.63 N 565067.18 E 0.000 4569.08 7200.00 '. 74.843 304.614 3915.96 3974.76 2290.54 N 4069.06 W 6018567.72 N 564987.24 E 0.000 4665.48 7300.00 74.843 304.614 3942.10 4000.90 2345.37 N 4148.49 W 6018621.81 N 564907.30 E 0.000 4761 .88 - 7400.00 74.843 304.614 3968.25 4027.05 2400.20 N 4227.93 W 6018675.90 N 564827.36 E 0.000 4858.28 7500.00 74.843 304.614 3994.40 4053.20 2455.02 N 4307.36 W 6018729.99 N 564747.42 E 0.000 4954.68 7600.00 74.843 304.614 4020.55 4079.35 2509.85 N 4386.80 W 6018784.08 N 564667.48 E 0.000 5051.08 7700.00 74.843 304.614 4046.69 4105.49 2564.68 N 4466.24 W 6018838.17 N 564587.54 E 0.000 5147.48 7762.38 74.843 304.614 4063.00 4121.80 2598.88 N 4515.79 W 6018871.91 N 564537.67 E 0.000 5207.61 Top Ugnu M - TUZB 7800.00 74.843 304.614 4072.84 4131.64 2619.51 N 4545.67 W 6018892.26 N 564507.59 E 0.000 5243.88 7900.00 74.843 304.614 4098.99 4157.79 2674.34 N 4625.11 W 6018946.35 N 564427.65 E 0.000 5340.28 8000.00 74.843 304.614 4125.13 4183.93 2729.17 N 4704.55 W 6019000.44 N 564347.71 E 0.000 5436.68 6 February, 2002 - 15:01 Page 30f6 DrillQuest 2.00.09.008 --- '-' .~ Sperry-Sun Drilling Services Proposal Report for MPE-13a - MPE-13 B WP-D5 Revised: 6 February, 2002 aska Drilling & Wells Milne Point Unit Milne Point MPE Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 8095.10 74.843 304.614 4150.00 4208.80 2781.31 N 4780.09 W 6019051.89 N 564271 0.000 5528.36 SBF2-NA 8100.00 74.843 304.614 4151.28 4210.08 2784.00 N 4783.98 W 6019054.53 N 564267.77 E 0.000 5533.07 8200.00 74.843 304.614 4177.43 4236.23 2838.83 N 4863.42 W 6019108.62 N 564187.83 E 0.000 5629.47 8206.02 74.843 304.614 4179.00 4237.80 2842.13 N 4868.20 W 6019111.88 N 564183.02 E 0.000 5635.27 SBF1-NB 8297.81 74.843 304.614 4203.00 4261.80 2892.46 N 4941.12 W :6019161.53 N 564109.64 E 0.000 5723.76 SBE4-NC .-- 8300.00 74.843 304.614 4203.57 , 4942.86 W 6019162.71 N 564107.89 E 0.000 5725.87 8400.00 74.843 304.614 4229.72 5022.29 W 6019216.80 N 564027.95 E 0.000 5822.27 8401 .07 74.843 304.614 4230.00 5023.14 W 6019217.38 N 564027.09 E 0.000 5823.31 SBE2-N E 8500.00 74.843 304.614 4255.87 ;,,5101.73 W 6019270.89 N 563948.01 E 0.000 5918.67 8573.18 74.843 304.614 4275.00 >5159.86 W 6019310.48 N 563889.51 E 0.000 5989.22 SBE1-NF 8600.00 74.843 304.614 4282.01 5181.16W 6019324.98 N 563868.06 E 0.000 6015.07 8632.16 74.843 304.614 4290.42 5206.71 W 6019342.38 N 563842.36 E 0.000 6046.07 Begin Dir @ 5.000°/1000 : 8632.16ft MD, 4349.22ft TVD 8684.79 73.000 302.659 4305.00 3103.79 N 5248.81 W 6019370.00 N 563800.00 E 5.000 6096.61 End Dir, Start Sail @ 73.000° : 8684. 79ftM D ,4363.8OOTVD TSBD-OA MPE-13B Target Poly, 250.00 Radius. 8700.00 73.000 '302.659 .. 4Q09t45 4368.25 3111.64N 5261 .05 W 6019377.74 N 563787.68 E 0.000 6111 .16 8800.00 7:3.000, 302;659' 4338.68 4397.48 3163.24 N 5341.57 W 6019428.59 N 563706.70 E 0.000 6206.78 8900.00 73.000, .302.659 4367.92 4426.72 3214.85 N 5422.08 W 6019479.45 N 563625.71 E 0.000 6302.39 8900.27 73:000 302.659 4368.00 4426.80 3214.99 N 5422.29 W 6019479.59 N 563625.49 E 0.000 6302.65 8951.33. 73.000 302.659 4382.93 4441.73 3241.34 N 5463.41 W 6019505.56 N 563584.14 E 0.000 6351 .48 Total Depth: 8951 .33ftM D ,4441 .73ftTVD - 7" Casing All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 301.740° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8951.33ft., The Bottom Hole Displacement is 6352.57ft., in the Direction of 300.680° (True). 6 February, 2002 - 15:01 Page 40f6 DrillQuest 2.00.09.008 "- Milne Point Unit Comments Measured Depth (ft) 2480.00 2500.00 3400.00 3850.35 8632.16 8684.79 8951 .33 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2418.63 2436.26 2979.64 3098.93 4349.22 149.37 N 151.61 N 285.84 N 453.96 N 3075.78 N 328.55 W 337.72 W 1011.07 W 1408.22 W 5206.71 W "-' "-".' 4363.80 4441.73 3103.79 N 3241.34 N 5248.81 W 5463.41 W Sperry-Sun Drilling Services Proposal Report for MPE-13a - MPE-13 8 WP-D5 Revised: 6 February, 2002 aska Drilling & Wells Milne Point MPE Comment Tie-on: Start Dir @ 12.0000/100ft: 2480.0OftMD,2418.63ftTVD Begin Dir @ 5.156°/100ft: 2500.000 MD, 2436.26ft TVD Continue build 5.000°/1000 End Dir, Start Sail @ 74.843° : 3850.35ftMD,3098.93ftTVD Begin Dir @ 5.000°/1 0 aft : 8632.16ft MD, 4349.22ft TVD -- End Dir, S~S¡,San @ 73.000° : 8684.79ftMD,4363.8OOTVD Total Deptlìi!'fi'8951.33ftMD,4441.73ftTVD Formation Tops Formati on Plane r i t¡¡'iiíí?"¡e net rat ion Poi n t (Below Well Origin) Measured V al Sub-5ea Sub-Sea Dip Dip Dir. Depth De th Depth Northings Eastings Formation Name (ft) Deg. p~g. (ft) (ft) (ft) (ft) (ft) 3672.00 0.000 ~ 0:531 '6266.97 3730.80 3672.00 1778.97 N 3327.89 W Top Ugnu -TUZC 4063.00 '9.000 ,0.531 7762.38 4121.80 4063.00 2598.88 N 4515.79 W Top Ugnu M - TUZB 4150.op O~OOQ , 0~531 8095.10 4208.80 4150.00 2781.31 N 4780.09 W SBF2-NA 4179.00 ,0.000 0.531 8206.02 4237.80 4179.00 2842.13 N 4868.20 W SBF1-NB 4203.00 t).OOO 0.531 8297.81 4261.80 4203.00 2892.46 N 4941.12 W SBE4-NC 4230.00 0.000 0.531 8401.07 4288.80 4230.00 2949.07 N 5023.14 W SBE2-NE 4275.00 0.000 0.531 8573.18 4333.80 4275.00 3043.44 N 5159.86 W SBE1-NF 4305.00 0.000 0.531 8684.79 4363.80 4305.00 3103.79 N 5248.81 W TSBD-OA 6 February, 2002 -15:01 - Page 50f6 . DrillQuest 2.00.09.008 -- Milne Point Unit Casing details Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surlace> <Surlace> 8951.33 4441 .73 Targets associated with this wellpath Target Name MPE-13B T1 Top OA MPE-13B Target 6 February, 2002 -15:01 .~ Sperry-Sun Drilling Services Proposal Report for MPE-13a - MPE-13 B WP-DS Revised: 6 February, 2002 Casing Detail 7" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) ean Sea Level/Global Coordinates: Geographical Coordinates: 4363.80 4305.00 3103.79 N 5248.81 W 6019370.00 N 563800.00 E 70027' 48.2742" N 149028'44.9014" W Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: 4363.80 4305.00 3103.79 N 5248.81 W 6019370.00 N 563800.00 E 70027' 48.2742" N 149028' 44.9014" W 250.000 Page 60f6 '-" Alaska Drilling & Wells Milne Point MPE ~ Target Target Shape Type Point Circle -- DrillQuest 2.00.09.008 """ - '''--~ .,-..-. "..Y-!!Lr1 B PXA 'bl1L.LfN~ .4i"vn-~J Milne Point Unit If. ""iW:+'<¡r.(,....,.......' 1 500 - Q) () c:: Q) Q; Q) a: ~ 2250 - J:: Õ. Q) 0 (ij () '€ Q) > 3000 - 3750 - .::: 0 It) ,.... II ..c 0 .£ Qj 4500 - ~ (f) r"<o_"'-..... ^ ^^ ^^ ......" 0 .1L!:11\ 750 - i""'''¡ Fftlt>J 0 Scale: 1 inch = 750ft '-- J ~~~~1~~nt MPE ÐrillQuest~ MPE-13 8 WP-oS Formations Single Well Target Data for MPE-138 Measured Vertical Sub-Sea Measurement lJnjls: ~S)th Depth Depth Dip ~~r Formation Name Coordi1ate (ft) (ft) (Deg) Target Poi1t TVD SSTVD Northi1gs Eastings ASP Northi1gs ASP Eastings Target 0,531 Top Ugnu -TUZC Name Type Shape 6266,97 3730,80 3672.00 0.1)00 7762.38 4121.80 4063,00 0.1)00 0.531 Top Ugnu M - TUZ1! MPE-I3B T1 TopOA Entry Point 4363,80 4305,00 3103,79N 5248,81 W 6019370.00 N 563800,00 E Point 8095,10 4208,80 4150,00 0,000 0,531 SBF2-NA 8206,02 4237.80 4179.00 0,000 0531 SBF1-NB ~ll'E- I3B Target Poly Entry Point 4363,80 4305,00 3103,79N 5248,81 W 6019370.00 N 563800,00 E Circle 8297,81 4261.80 4203,00 0,000 0531 SBE4-NC 8401.07 4288,80 4230,00 0,000 0,531 SBE2-NE 8573,18 4333,80 4275,00 0,000 0,531 SBEI-NF 8684,79 4363.80 4305,00 0,000 0,531 TSBD-OA Measured Vertical Comment Depth Depth (ft) (ft) 2480,00 2500.00 3400.00 385035 8632J6 8684,79 895133 '-, .. .. Begn Dir @ 5,156'/100II: 2500,00" MD. 2436,26"lVD .' . . JØf,t' MPE-13 8 WP-oS Comments "-' 2418,63 2436.26 2979,64 3098,93 4349.22 4363,80 4441.73 1ie-on: Stan Dir @ 12JlOO'/I00ft: 2480,OOftMD.2418,63ft1VD Begin Dir @ 5,156'/IOOft: 2500,OOft MD. 2436,26ft1VD Continue build 5J)OO'/IOOft End Dir, Star! SaH @ 74,843' : 385035ftMD,3098,93ft1VD Begin Dir @5,OOO'/IOOft:8632J6ftMD.4349,22ft1VD End Dir. Star! Sail @ 73.1100': 8684,79ftMD,4363,80ftlVD Total Depth: 895L33ftMD.444L73ft1VD WeD: Hoñzontal Coordinates: ReI. Global Coordnates: 6016315,01 N. 569077,36 E ReI. Structure Reference: 2519,59 N. 340.01 W Ref. Geographical Coordinates: 7O' 27' 17.7645" N. 149' 26' 10,6400" W Current Well Properties MPE-13B ¡Continue btild 5,000'/100II 300~ -- /nd Dir. Start Sail @ 74,843' : 3850.35"MD.309B,93ftTVD _1700.00 -4100,00 RKB Elevation: North Reference: Units : _4500.00 4900DO G300.oo -G700lJO '£100,00 I 750 I 2250 I I 3000 3750 Vertical Section (Well Reference) 5B,BOft above Mean Sea Level 5B,BO" above Structure Reference True North Feet (US) .~. '£500,00 MPE~138 T1 TøOA 43f-3.BO TVD. 1>900,00 3=0:?-.79 !-~, 5248.81 W Alp£. 1. 3300,00 . 38Wp.OS MPE-::?-B Ta~get Pey 4~63.S~, TVD. 3~C3.79 N 52~;..3.S: 1:,/:;' Ra:;¡us: ¿50.~;Qf~ / T Casi'g .11500,00 8951 ,33'1.4 D 'm...e...~~ 4441,731V0 Total ~pth: 8951.33ftMD. 4441.73ftlVD 3700,00 Jl100,OO Begin Dir @ 5,000'/100": B632.16ft MD. 4349.22ft lVD End Dir, Start Sail @ 73,000' : B684.79"MD,4363.801tTVD I 4500 I I 5250 6000 Section Azimuth: 301.740° (True North) ) ) i 204446 DATE 01/17/02 CHECK NO. 00204446 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 100.00 00 D11602 CK011602M PYMT ::;OMMENTS: HANDLING INST: Per~it to Drill Fee 5tH - Terrie HubJle X4628 RECEIVED ~E~- i3ß\ FES 2 2 2002 Alaska Oil & Gas Cons. Commission Anchorage . ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 204446 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 4'12 00204446 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 ç¿~ {3/v\L(--~ III 20 L. L. l. b III I: 0 ~ ~ 2 0 j a ~ 5 I: 0 0 a l. l. ~ ~ III .~; ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMßTTALLETTER WELL NAME J7l ¡? Ú f~ - / ~3 13 ,~ <.. CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL INJECTION WELL REDmLL/ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) .- .l /' I ANNULAR?IS SAL L-) 0 \ ANNULAR DISPOSAL L..J YES ANNULAR DISPOSAL THIS WELL' "CLUE" Tbe permit is for a Dew wellbore segment of existing well ~ Permit No, ,AP~ No. ' " Production should continue to be reported as a function of tbe original API number stated above. ' In accordance with 2,0 MC 25.005(1), all records, data and logs acquired for tbe pilot hole must be clearly . differentiated in both name (name on permit plus PH) and API number (SO -70/80) from records, data and logs acquired for wel~ (n8:me on permit). Annular disposal bas ~ot been requested. . . 'Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved.. . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated. '. . ANNULUS L..J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbJect to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to the spacing exception tbat may occur. WELL PERMIT CHECKLIST COMPANY .~ WELL NAME JJ1pt! E-!375/ FIELD & POOL 52-.51'-/() INITCLASS ~ ItU/AlJ -""" ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . i' N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . N AP~ DATE 12. Permit ca~ be issued without administrativ~ approval.. . . . . , N ~ 2 "2,6 .D"¿ 13. Can permit be approved before 15-day walt.. . . . . . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥---N-/'-'/Æ I 15. Surface casing protects all known USDWs. . . . . . . . . . . ..vA Y N - 4-- dr' /( JZ .....e..~/s-hn.r 16. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥---N- 0 J 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y @ . j 18. CMT will cover all known productive horizons. . . . . . . . . . i NÂck, LoA..-~ «tesç ~::t¡. 19. Casing designs adequate for C, T, B & permafrost. . . . . . . , N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N NOt. be/v ~ 2... 1 F 21. If a re-drill, has a 10-403 for abandonment been approved. . . '"* N 22. Adequate wellbore separation proposed.. . . . . . . . . . . . , N 23. If diverter required. does it meet regulations. . . . . . . . . . ~ ¡..i1A- 24. Drilling fluid program schematic & equip list adequate. . . . . W/ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . J N I A~ Ii' ,~R.L.. D~ TIE 26. Bo.PE press rating appropriate; te"stto 't.¡ S 00 psig. N /v'lR:> P = (Ç 05 P ~ IYJ.W'\ ;/ICL. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ,N 1~, "," ,"'2. 28. Work will occur without operation shutdown. . . . . . . . . . . '5tJ N t::'t}::~ ;J I, 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y 6) GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . cÐ ~ 31. Data presented on potential overpressure zones. . . . . . . A~N 32. Seismic analysis of shallow gas zones. . . . . . . . . . ~.. t\ Y N AP~~ DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N ~ b 'Z' z¿, .0-2..34. Contact name/phone for weekly progress reports [explo ry only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will npt contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGIN~~RING',' UIC/Annular: COMMISSION: RPC~ TEM ¥?Jft3/, COT, , SFD~ WGA'~~ DTS({)3/c>/!ð2- .. JMH ðfll4f- .;}fa { I ~ APPR DATE Y N Y N G:\geology\templates\checklist.doc PROGRAM: Exp - Dev - Redrll ~Serv ~~ellbore seg - Ann. disposal para req - GEOL AREA f?9û UNIT# all. --=32B ON/OFF SHORE OA. ~~¡:C-~ ,d, c.41z~ ~ ./f7:::>,-- OZ~Ç/8; h"tP~ ~'~4 ~ 'r. b: "',~ 0 '17 ¥'37 "ù- (" ¿~( .~¡/¿:...y-'~~ ~~~ ~~ ß',G~ ~~ð ~¿J \ N~ 4<Ak..t/.C<'/ t 'P ~~ { Y"ptPj bJ . Comments/Instructions: ). ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process' but is part of the history file. To improve the readabiltty of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ') ) aO¿;,Ol/ Y 10 '1 '-Is Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 14 08:46:57 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Date........... ..........02/06/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments. ...... ......... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/06/14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Pt. MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPE-13B 500292253602 BP Exploration Alaska, Inc. Sperry-Sun Drilling Services 14-JUN-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AK-MW-22054 A. WEAVER E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 25 13N 10E 3778 2067 MSL 0) 59.00 24.40 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2506.0 ) , 3 RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). THIS RUN WAS TO SET THE WHIPSTOCK AND DRILL OUT. THE TOP OF THE WINDOW IS 2506/MD AND THE BOTTOM OF THE WINDOW IS 2522/MD. NEW FORMATION WAS MILLED TO 2541/MD. NO FE DATA WERE ACQUIRED FOR THIS RUN. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR AND EWR4. 5. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY LOG RUN IN MPE-13B ON 24 APRIL 2002. THESE PDC DATA WERE PROVIDED TO SSDS BY DEWAYNE SCHNORR ON 11 JUNE 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUN 2 REPRESENTS WELL MPE-13B WITH API#: 50-029-22536-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8850.5/MD/4437.95/TVD (SHIFTED DEPTHS) . SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS/ REFLECTING BIT DEPTHS $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/06/14 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD 1 ) " Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPX RPS RPM RPD FET GR ROP $ and clipped curves; all bit runs merged. .5000 START DEPTH 2498.5 2498.5 2498.5 2498.5 2498.5 2506.5 2555.5 STOP DEPTH 8807.5 8807.5 8807.5 8807.5 8807.5 8815.5 8850.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE DEPTH GR 2498.5 2497.5 7696.5 7695.5 7710.5 7711.0 7763.0 7761.5 7778.0 7779.5 7803.0 7801.5 7880.5 7882.0 7912.0 7912.0 7954.5 7955.0 7962.5 7962.5 7985.5 7986.0 8007.0 8008.0 8015.0 8016.0 8029.5 8030.5 8131.0 8131.0 8207.0 8208.0 8226.5 8227.0 8249.5 8250.5 8282.0 8284.0 8337.5 8339.0 8634.5 8635.0 8688.5 8689.5 8851.0 8852.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2497.5 8851.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing. - -................. .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ) ) ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2498.5 8850.5 5674.5 12705 2498.5 8850.5 ROP MWD FT/H 4.41 1110.49 329.576 12591 2555.5 8850.5 GR MWD API 6.29 129.71 67.6986 12619 2506.5 8815.5 RPX MWD OHMM 1.18 2000 8.74624 12619 2498.5 8807.5 RPS MWD OHMM 1.14 2000 9.45977 12619 2498.5 8807.5 RPM MWD OHMM 0.73 2000 11.3242 12619 2498.5 8807.5 RPD MWD OHMM 0.38 2000 13.3343 12619 2498.5 8807.5 FET MWD HOUR 0.05 22.15 0.534599 12619 2498.5 8807.5 First Reading For Entire File......... .2498.5 Last Reading For Entire File.......... .8850.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/06/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/06/14 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM RPD FET GR ROP 2 header data for each bit run in separate files. 2 .5000 START DEPTH 2497.5 2497.5 2497.5 2497.5 2497.5 2505.5 2554.5 STOP DEPTH 8808.5 8808.5 8808.5 8808.5 8808.5 8816.5 8851.5 ) $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 01-APR-02 Insite 66.37 Memory 8852.0 2541.0 8852.0 37.0 77.1 TOOL NUMBER PBOO123HGRV6 PBOO123HGRV6 8.500 2506.0 Water 9.00 63.0 8.0 1000 5.8 Based 2.900 1.890 3.400 3.900 66.0 105.0 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 ) ) GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2497.5 8851.5 5674.5 12709 2497.5 8851.5 ROP MWD020 FT/H 4.41 1110.49 329.547 12595 2554.5 8851.5 GR MWD020 API 6.29 129.71 67.6892 12623 2505.5 8816.5 RPX MWD020 OHMM 1.18 2000 8.74613 12623 2497.5 8808.5 RPS MWD020 OHMM 1.14 2000 9.45986 12623 2497.5 8808.5 RPM MWD020 OHMM 0.73 2000 11.3243 12623 2497.5 8808.5 RPD MWD020 OHMM 0.38 2000 13.3336 12623 2497.5 8808.5 FET MWD020 HOUR 0.05 22.15 0.534982 12623 2497.5 8808.5 First Reading For Entire File......... .2497.5 Last Reading For Entire File.......... .8851.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/06/14 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 06 / 14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/06/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF